0061-001837-701-1 model (1) - portal.sunbeltusa.comportal.sunbeltusa.com/images/content/standard...

H-8 20 AMP— 4, 5, 6,7,8, & 13 TERMINALCURRENT TRANSFORMER RATED—RINGLESS / RING TYPE nnMILBANK

feKo5xt/i2os

2o

i ,.,

UC7852-YL UC7237-RL

RINGLESS—PLUNGER TYPE BYPASS

NO.OF

TERMS

4

5

6

7

8

13

SERVICE

OH/UG

OH/UG

OH/UG

OH/UG

OH/UG

OH/UG

CATALOGNUMBER

UC1288-XL

UC1290-XL

UC1299-XL

UC7233-XL

UC7235-XL

UC7237-XL

HUB

C.P.

C.P.

C.P.

C.P.

C.P.

C.P.

CONNECTORSCU

#14 -#10

#14 -#10

#14 -#10

#14 -#10

#14 -#10

#14 -#10

BY-PASS

YES*

YES*

YES*

YES*

YES*

YES*

DIMENSIONS

D"

35/,6

3^6

35/16

35

'6

35/16

35/,6

W"

8

8

8

8

8

8

H"

14

14

14

14

14

14

CONCENTRIC K.O.'S

1

1 1/2

11/2

11/2

1 ','2

1 V2

Vk

2

Vk

1 %

1 1/2

1 '/2

1'/2

11/2

3

1%

1 1/4

1 !'4

1 '/4

1 'A

1 'A

4

1 'A

1 1/4

1%

11/4

1 '/4

1 1/4

5

1 'A

1%

1%

11'4

1 'A

1 'A

6

%

1A

1/

/4

/4

1//4

• BYPASS: Plunger type bypass automatically closes when meter is removed.• HUBS: For proper hub selection, see hub suffix chart in the accessory section.

RING TYPE—WITHOUT BYPASS

NO.OF

TERMS

4

5

6

7

8

13

SERVICE

OH/UG

OH/UG

OH/UG

OH/UG

OH/UG

OH/UG

CATALOGNUMBER

UC3594-XL

UC3595-XL

UC3596-XL

UC2421-XL

UC7746-XL

UC7582-XL

HUB

C.P.

C.P.

C.P.

C.P.

C.P.

C.P.

CONNECTORSCU

#14 -#10

#14 -#10

#14 -#10

#14 -#10

#14 -#10

#14 -#10

BY-PASS

NONE

NONE

NONE

NONE

NONE

NONE

DIMENSIONS

D"

35/ie

35'16

35'',6

3%6

3^,6

3^16

W"

8

8

8

8

8

8

H"

14

14

14

14

14

14

CONCENTRIC K.O.'S

1

1 !/2

1 !<2

11'2

1!'2

1 VI 12

11/2

2

1%

11/2

1 '/2

1'/2

1V2

Vk

3

1 1/4

1 V'4

1 'A

1 'A

11A

1 'A

4

11A

11A

1 1A

1'A

1 'A

11A

5

1%

1 '/4

1 1/4

1 '/4

1 1 4

1 !A

6

1,'

t4

%

1/

/4

'A

?I*0$t^*-u^tv

^1?^• SEALING RING: Ring type units are supplied with one MR-4, screw type sealing ring.• HUBS: For proper hub selection, see hub suffix chart in the accessory section.• RING TYPE: Plunger bypass is available in ring type. Consult factory.

Section H-8

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

cbryant

Highlight

1-2 MISCELLANEOUS MILBANK ACCESSORIES mMILBANK

INTERCHANGEABLE UNIT HUBS

REMOVABLE HUBCLOSING PLATE

SMALL "RL"OPENING (STANDARD)

LARGE "R"OPENING (HEAVY DUTY)

SIZE

STANDARD(for -RL opening)

LARGE(for -R opening)

SUFFIX

-XL

-X

CAT. #

A7551

S9064

SUFFIX

-WL-YL-ZL-DL-EL

SIZE

1"

11//'11/2"

2"

21/2"

MILBANKNO.

A7514

A7515

A7516

A7517

A7518

SUFFIX

-F-G-H

SIZE

3"

3';2"

4"

MILBANKNO.

A8110

A8111

A8112

HUB ADAPTER PLATE(Converts -R opening to -RL)

S8324

CLOSING COVERSHUB SUFFIX CHART

0RLR

XLX

RXL

RRL

Plain Top

Small Hub Opening

Large Hub Opening

Small Closing Plate

Large Closing Plate

Large Hub Openingadapted to small Closing Plate

Large Hub Openingadapted to small Hub Opening

WLYLZLDLEL

F

G

H

1"1 V/'1 Vz"

2"

21/2"

3"

3V

4"

For -RL Opening

For -RL Opening

For -RL Opening

For -RL Opening

For -RL Opening

For -R Opening

For -R Opening

For -R Opening

METER CLOSING PLATE(Gray Plastic)

6003(Ring Type / Ringless)

METER CLOSING PLATE(Clear Plastic)

6116(Ring Type / Ringless)

METAL CLOSING PLATE(Ringless sockets only)

CP-21

METAL CLOSING PLATE(Ring Type sockets only)

MCP

SAFETY SWITCH HUBS

SMALL "RL"OPENING (STANDARD)

LARGE "R"OPENING (HEAVY DUTY)

SUFFIX

-WL-YL-ZL

SIZE

1"

1 vTi1/2"

MILBANKNO.

A7514-SW

A7515-SW

A7516-SW

SUFFIX

-DL-EL

-F

SIZE

2"21/2"

3"

MILBANKNO.

A7517-SW

A7518-SW

A8110-SW

SINGLE

SINGLE CONNECTOR KITS

SUFFIX

-K1-K3

SUFFIX

-K5-K7

CATALOG #

K1539

K1540

CATALOG #

K3082

K3441

(3 per set) -10

350 kcmil (MAX)

600 kcmil (MAX)

(4 per set) - 3 0

350 kcmil (MAX)

600 kcmil (MAX)

^^^^BREAKER MOUNTING CLIP

(for RV/MH pedestals)K3785

CONNECTOR KITS

For use with 3/8"-16 studtype units only

TWIN

TWIN CONNECTOR KITS

SUFFIX

-K2-K4

SUFFIX

-K6-K8

CATALOG #

K1350

K1541

CATALOG #

K3442

K3083

(3 per set) -10

350 kcmil (MAX)

600 kcmil (MAX)

(4 per set) -30

350 kcmil (MAX)

600 kcmil (MAX)

Section J-2

mMILBANK MATERIALS & FINISHES J-7

MATERIALS

STEEL QUALITY

The meter equipment listed in this catalog is made of galvanized steel (G90U or AGO) to affordthe best possible weather proofing. *American Iron and Steel Institute.

STEEL SHEET

16 gauge, galvanized, sheet: 1 1/4 oz./ sq.ft. class zinc-coated.(AISI G90) (AISI A60)14 gauge, galvanized, sheet: 1 1/4 oz./ sq.ft. class zinc-coated.

ALUMINUM EXTRUSION

Wire-Terminals: Alloy; 6061-T6, Tin-plated for Cu/AI wire.Bus Bar: Alloy; 6101-O & 6063-O

ALUMINUM SHEET

3000 series aluminum sheet, H14, or 5052 series aluminum sheet, H32. Where applicable thick-ness range from .064 — .125

COPPER SHEET & BUS

Electrolytic copper with tin plating in most applications.

INSULATING MATERIALS

In most units support bases for current carrying components are molded from fiberglass rein-forced high-strength, track resistant, thermoset polyester molding compounds. .̂Clear or black safety shields and polarity barriers are molded from high-strength, track resistant, i*.polycarbonate molding compounds. i?jVarious sheet insulating materials as appropriate for the application are utilized in the fabrication ^of flat, formed and punched component parts and barriers. i—

FINISH 3g

PROCESS £5

Light gray "state of the art" electrostatically applied powder paint offers a durable, non-fadingfinish. For further information concerning the chemical analysis of the weather resistant finish,please contact the factory.

METAL FASTENERS

Zinc-coated with a chromate dip.

RATING

NEMA RATING

All Milbank meter sockets, CT cans and meter socket / breaker units have a Nema 3R rating.

Section J-7

The build-a-meter concept provides

modular growth in the S4e with software

upgrades for time-of-use, reactive energy

metering, single-level transformer loss

compensation, load profile, as well as the

flexibility of adding any combination of

communication and relay option boards.

S4/S4e Family of Solid State Meters Instruction/Technical Manual

Bulletin 987 Revision 5

i

Information in this document is subject to change without notice. No part of this document may be reproduced or transmitted in any form or by any means, electronic or mechanical, for any purpose without the express written permission of Landis+Gyr Inc.

1997, 2002, 2003, 2004 Landis+Gyr Inc

All rights reserved. For further information, contact: Landis+Gyr Inc 2800 Duncan Road Lafayette, IN 47904 USA Tel. 765-742-1001 or 800-777-2774 Fax 765-742-0936 Web: http://www.landisgyr.com

Document History Title: S4/S4e Solid State Meter Instruction/Technical Manual

Document Number: 987

Revision Date Description Level Issued Original 9/1996 Initial Issue Revision 1 2/1997 Revision 2 5/1998 Revision 3 11/2002 Landis+Gyr Name Change Revision 4 11/2003 ANSI Protocol and S4e Additions, General Updates Revision 5 5/2004 Added block diagram and Landis+Gyr Formatting

TABLE OF CONTENTS LIST OF TABLES ..................................................................................................... X

LIST OF FIGURES .................................................................................................. X

SAFETY WARNINGS ............................................................................................. XI

1. INTRODUCTION TO THE S4 AND THE S4E ..................................................... 1

1.1 The S4 and the S4e ......................................................................................................... 1

1.2 The S4 Meter Family ....................................................................................................... 2

1.3 ServiceScan Automatic Meter Service Type Recognition ............................................... 2

1.4 GyrBox Installation Diagnostics ..................................................................................... 2

1.5 Software and Software Upgrades ................................................................................... 2

1.6 Inputs / Outputs ............................................................................................................. 3

1.7 Communications ............................................................................................................. 4

1.8 Advanced Feature Sets ................................................................................................... 4

1.8.1 Expanded Load Profile of 32K or 128K Bytes ......................................................................... 4

2. APPLICATION INFORMATION ........................................................................ 5

2.1 Available Meter Forms by Base and Class ...................................................................... 5

2.2 Installation Procedures ................................................................................................... 5

2.3 Battery Installation (for TOU applications) .................................................................... 6

2.3.1 Battery Carryover Time ........................................................................................................ 6

3. OPERATING INSTRUCTIONS ...................................................................... 7

3.1 Overview of Electronic Hardware ................................................................................... 7

3.1.1 LCD Display ......................................................................................................................... 7

3.1.2 Diagram of Parts .................................................................................................................. 8

3.1.3 Switches .............................................................................................................................. 9

3.1.4 Optical Port/ Calibration LED ................................................................................................ 9

3.1.5 Programmable Outputs/Inputs ........................................................................................... 10

3.2 Initial Power-Up and Operation .................................................................................... 10

3.2.1 Unprogrammed Displays .................................................................................................... 10

3.2.2 Programming Equipment .................................................................................................... 10

3.2.3 Manual Loading of Service Type ......................................................................................... 11

3.3 Accessing the Display Modes ........................................................................................ 11

3.4 Scroll Modes .................................................................................................................. 12

3.4.1 Auto-scroll Mode ................................................................................................................ 12

3.4.2 Manual Scroll Mode ............................................................................................................ 13

3.4.3 Scrolling in the Alternate Display Sequence ......................................................................... 13

3.4.4 Scrolling in the GyrBox Mode .............................................................................................. 13

4. TEST MODE ................................................................................................... 14

4.1 Test Mode Display ......................................................................................................... 14

4.2 Actions Upon Entering Test Mode ................................................................................. 14

4.3 Action Upon Exiting Test Mode ..................................................................................... 14

4.4 Test Mode Demand Functions ....................................................................................... 14

4.5 Operation of Outputs During Test Mode ....................................................................... 14

4.6 Miscellaneous Functions During Test Mode ................................................................. 14

4.7 Test Mode Time-out ...................................................................................................... 15

5. GYRBOX OPERATION ................................................................................... 16

5.1 Overview of GyrBox ...................................................................................................... 16

5.1.1 ServiceScan: Service Recognition and Verification ............................................................... 16

5.1.2 Service Scan Displays ......................................................................................................... 16

5.1.3 Programmable Service Types ............................................................................................. 17

5.1.4 GyrBox Activation............................................................................................................... 17

5.2 Methods for entering GyrBox ........................................................................................ 17

5.2.1 Digital Power Indicator (DPI) during GyrBox Activation ........................................................ 18

5.2.2 Display Format and Reference ............................................................................................ 18

5.2.3 GyrBox Display List ............................................................................................................ 19

5.2.4 Diagnostic Counters ........................................................................................................... 20

5.2.5 Diagnostic Check Display Options ....................................................................................... 20

5.3 Diagnostic Checks ......................................................................................................... 20

5.3.1 D1 (Polarity and Cross-phase) ............................................................................................ 20

5.3.2 D2 (Phase Voltage Deviation Check) ................................................................................... 21

5.3.3 D3 (Inactive Phase Current Check) ..................................................................................... 21

5.3.4 D4 (Phase Angle Displacement Check) ................................................................................ 21

5.3.5 D5 (Future) ....................................................................................................................... 21

5.3.6 D6 (Current Magnitude Imbalance Check) ........................................................................... 21

5.3.7 D7 (Energy Polarity Check) ................................................................................................. 21

5.4 Normal phase angles..................................................................................................... 22

5.4.1 3-Wire Network Service ...................................................................................................... 22

5.4.2 3-Wire Delta Service .......................................................................................................... 23

5.4.3 4-Wire Wye Service ............................................................................................................ 24

5.4.4 4-Wire Delta Service .......................................................................................................... 26

5.5 Common sources for diagnostic alerts ......................................................................... 28

6. DEMAND METERING ..................................................................................... 33

6.1 DEMAND TYPES ............................................................................................................. 33

6.1.1 Thermal Demand ............................................................................................................... 33

6.1.2 Five Highest Demands ....................................................................................................... 34

6.2 Demand (Billing Period) Reset ..................................................................................... 34

6.2.1 Automatic Demand Reset upon Season Change .................................................................. 35

6.2.2 Season Change upon Demand Reset .................................................................................. 35

6.2.3 Demand Reset Methods ..................................................................................................... 35

6.2.4 Power on demand delay timing .......................................................................................... 35

7. TOU METERING ............................................................................................. 36

7.1 Main Clock ..................................................................................................................... 36

7.2 Time Display Format ..................................................................................................... 36

7.3 Date Display Format ..................................................................................................... 36

7.4 Date and Time Setting .................................................................................................. 36

7.5 Daylight Savings Time .................................................................................................. 36

7.6 Time On Carryover ........................................................................................................ 37

7.7 Programmable Dates and Schedules ............................................................................ 37

7.7.1 Programmable Dates ......................................................................................................... 37

7.7.2 Seasonal Rate Changes ...................................................................................................... 37

7.7.3 TOU Daily Schedules .......................................................................................................... 37

7.7.4 Day Select for Schedules .................................................................................................... 37

7.8 Load Control/TOU Switchpoints ................................................................................... 38

7.9 Rate Indicator Outputs ................................................................................................. 38

7.10 Load Profile ................................................................................................................... 38

7.10.1 Load Profile Memory Capacity ........................................................................................ 38

7.10.2 Automatic Upgrade/Downgrade of Load Profile Memory .................................................. 38

7.10.3 Load Profile Interval Length ........................................................................................... 39

7.10.4 Load Profile Recording Channels ..................................................................................... 40

7.10.5 Load Profile Pulse Values ............................................................................................... 40

7.10.6 Load Profile Error Detection ........................................................................................... 41

7.10.7 Long Outage Detection .................................................................................................. 41

7.10.8 Date and Time of Last Load Profile Interval Read ............................................................ 41

7.11 Real Time Billing ........................................................................................................... 42

7.12 Master Reset ................................................................................................................. 42

7.13 Cold Starts ..................................................................................................................... 42

7.13.1 Method 1, Optical Cold Start........................................................................................... 42

7.13.2 Method 2, Manual Cold Start .......................................................................................... 43

7.13.3 Register Displays following a Cold Start .......................................................................... 43

7.14 ANSI Type II Optical Communications Port ................................................................. 43

7.15 Security ......................................................................................................................... 43

7.15.1 S4 and S4e DGCOM Security Information ........................................................................ 44

7.15.2 S4e ANSI Security Information ....................................................................................... 44

7.16 Voltage Quality Information ......................................................................................... 45

7.16.1 Sag Information ............................................................................................................ 45

7.16.2 Swell Information .......................................................................................................... 45

7.16.3 Voltage Sag Alert ........................................................................................................... 46

7.16.4 Voltage Swell Alert ......................................................................................................... 46

7.16.5 Instantaneous Readings ................................................................................................. 46

7.17 Self-Reads ..................................................................................................................... 46

7.17.1 Self-Read Data .............................................................................................................. 46

7.17.2 Number of Self-Reads .................................................................................................... 47

7.17.3 Self-Read at Season Change .......................................................................................... 47

7.17.4 Initiating a Self-Read ..................................................................................................... 47

7.17.5 Self Read Displays ......................................................................................................... 48

8. OUTPUTS, INPUTS, AND COMMUNICATIONS .............................................. 49

8.1 Output Cables and Connectors ........................................................................................... 49

8.2 Inputs 1 and 2 ............................................................................................................... 50

8.2.1 Real-Time Communication Links ......................................................................................... 50

8.2.2 External Load Profile Inputs................................................................................................ 50

8.3 Output Relays 1-4 ......................................................................................................... 51

8.3.1 KYZ Pulse Outputs ............................................................................................................. 51

8.3.2 KYZ Pulse Constant Ke ....................................................................................................... 51

8.3.3 TOU Load Control .............................................................................................................. 52

8.3.4 End of Interval Output (EOI) .............................................................................................. 52

8.3.5 Demand Threshold Alerts (DTA) ......................................................................................... 52

8.3.6 Power Factor Threshold Alerts (PFTA) ................................................................................. 52

8.3.7 Voltage Threshold Alerts (VTA) ........................................................................................... 52

8.3.8 Diagnostic Alerts ................................................................................................................ 52

8.3.9 Operation of Outputs During Test Mode .............................................................................. 53

8.4 Electrical Specifications for KYZ Boards (absolute maximums) .................................. 53

8.5 Optical Port Communications ....................................................................................... 53

8.6 MODEM Communications Board ................................................................................... 53

8.6.1 Basic Operation ................................................................................................................. 53

8.6.2 Hardware Description ......................................................................................................... 54

8.6.3 Power Up Actions ............................................................................................................... 54

8.6.4 Operating Modes ............................................................................................................... 54

8.7 RS-232/RS-485 Communications Board ...................................................................... 55

9. TROUBLESHOOTING AND ERROR CODES .................................................... 56

9.1 Error Codes .................................................................................................................... 56

9.1.1 Low Battery Error (ERR 000001 or 000002)......................................................................... 56

9.1.2 Unprogrammed Register Error (ERR 000010) ...................................................................... 56

9.1.3 Memory/Load Profile Error (ERR 000100) ............................................................................ 57

9.1.4 Demand Overload Error (ERR 001000 or ERR 002000) ........................................................ 57

9.1.5 Stuck Switch Error (ERR 010000 or ERR 020000)) ............................................................... 57

9.1.6 Unsafe Power Fail Error (ERR 100000) ................................................................................ 57

9.1.7 Phase Error (ERR 000200) .................................................................................................. 58

9.1.8 Measurement Diagnostics Failure (ERR 200000) .................................................................. 58

9.2 Disabling Display of Error Codes ................................................................................... 58

10. MEASUREMENT TECHNIQUES ................................................................... 59

10.1 Metric Calculations ........................................................................................................ 59

10.1.1 Vectoral Metrics ............................................................................................................. 59

10.1.2 RMS Metrics .................................................................................................................. 59

10.2 Digital Implementation ................................................................................................. 60

10.2.1 Overview of S4 Implementation ..................................................................................... 60

10.2.2 Input Circuitry ............................................................................................................... 60

10.2.3 Sampling Rate ............................................................................................................... 60

10.2.4 Register Section............................................................................................................. 60

10.3 Negative Energy Metric ................................................................................................. 61

10.3.1 Security (Add) Mode ...................................................................................................... 61

10.3.2 Detent (Ignore) Mode .................................................................................................... 61

10.3.3 Net Mode ...................................................................................................................... 61

10.3.3 Leading kVARh Accumulator ........................................................................................... 61

10.3.4 VArms, kVARtd, kVAtd measurements ............................................................................ 61

10.4 50 Hz Operation ............................................................................................................ 61

10.5 Power Quadrant Indicators .......................................................................................... 62

10.6 Overview of the S4 Measuring Element ........................................................................ 62

10.6.1 S4 Measurement Metrics—Second (kM) and Third Metric (kM3) ....................................... 63

10.6.2 Neutral Current Calculations ........................................................................................... 63

10.6.3 Register Metric-Hour Constant (Kh) ................................................................................ 63

10.6.4 Transformer Factor (TF) ................................................................................................. 64

10.7 Power Factor ................................................................................................................. 64

10.7.1 Available Power Factor Measurements ............................................................................ 65

10.8 Effects of Harmonic Distortion ...................................................................................... 65

11. CALIBRATION VERIFICATION AND TESTING .......................................... 66

11.1 S4 Factory Calibration ................................................................................................... 66

11.2 How To Verify The S4 Calibration ................................................................................. 66

11.2.1 Verification of Watt Calibration ....................................................................................... 66

11.2.2 Calibration Pulse Displays ............................................................................................... 66

11.2.3 Test Times .................................................................................................................... 66

11.2.4 Field Testing .................................................................................................................. 67

11.2.5 Demand Measurement Verification ................................................................................. 67

APPENDIX A: TECHNICAL SPECIFICATIONS ........................................................ 1

No Load (Creep) ............................................................................................................................... 2

APPENDIX B: REGISTER DISPLAYS ...................................................................... 1

Display Formats................................................................................................................................ 2

Register Displays, listed alphabetically ............................................................................................... 4

APPENDIX C: POLYPHASE SERVICE TYPES .......................................................... 1

Form 9S/8S, 10A/8A Service Type Table ............................................................................................ 1

Form 29S, 36S (6S), 36A (6A) Service Type Table .............................................................................. 1

Form 45S (5S), 45A (5A) Service Type Table ..................................................................................... 2

Form 16/15/14S, 16/15/14A, 16/15/14K Service Type Table ............................................................... 3

Form 12S, 12SE, 12K, 25S, 27K (Network) Service Type Table ........................................................... 4

APPENDIX D: METER FORMS ................................................................................ 1

APPENDIX E: DEFINITIONS .................................................................................. 1

APPENDIX F: BLOCK DIAGRAM WITH LEGEND .................................................... 1

Legend ......................................................................................................................................... 2

APPENDIX G: NOTES AND NOTICES ..................................................................... 1

List of Tables Table 3.1.6 Programmable Input ratings

Table 3.2.1 Unprogrammed Displays

Table 5.2.3 GyrBox Displays

Table 6.0 Demand Subintervals/Intervals

Table 7.10.3 Number of Days in Different Load Profile Configurations

Table 7.10.4 Load Profile Metrics

Table 7.10.5.1 V2h/Vh Pulse Values

Table 7.10.5.2 I2h/Ih Pulse Values

Table 7.15 Security Levels and Corresponding Operations

Table 8.0 Option Board Inputs/Outputs

Table 8.1 Output Cables

Table 9.1 Error Codes

List of Figures Figure 1.1 S4 Meter

Figure 1.6 Option Board

Figure 2.1 Wiring Diagrams for 45S (5S), 36S (6S)

Figure 2.3 Battery Installation Procedures

Figure 3.1.1 LCD Display

Figure 3.1.3 S4 Switches

Figure 3.1.2 Exploded Diagram of S4

Figure 5.2.2 Sample GyrBox Display on LCD

Figures 5.4.1-5 Suggested KYZ Output Connection

Safety Warnings The following safety precautions must be observed during all phases of operation, service, and repair of this device. Failure to comply with these precautions or with specific warnings elsewhere in this manual violates safety standards of design, manufacture, and the intended use of the metering instrument. Landis+Gyr Inc assumes no liability for the customer's failure to comply with these requirements.

Warning: Any work on, or near, energized meters, meter sockets, or other metering equipment can present a danger of electrical shock. All work on this product should be performed only by qualified electricians and metering specialists in accordance with local utility safety practices, utility requirements and procedures outlined in Chapter 14 of The Handbook for Electricity Metering (9th edition). The information contained within this manual is intended to be an aid to qualified metering personnel. It is not intended to replace the extensive training necessary to handle metering equipment in a safe manner.

Use care when servicing with the power on.

Be aware that dangerous voltages exist at several points within the meter when this product is installed on a meter base.

Disconnect power before meter disassembly, soldering, or replacing components.

The S4 meter is connected directly to line potential. Due to the possibility of the potential lines being reversed, points accessible with the cover off may be at line voltage.

LINE POTENTIAL IS PRESENT ON THE INCOMING CONNECTORS ON THE MEASUREMENT BOARD INCLUDING THE BATTERY CONNECTOR.

The connectors have full length insulators crimped onto each connector and are shielded by the housing, but pulling the connector loose will expose the open end and line potential. The option board is connected directly to the main board and may also be at a high potential. A Mylar shield prevents touching the option board. Removing the Mylar shield exposes line voltage. The above warning label is affixed to the meter frame and identifies hazards in the meter.

Any option or I/O cables connecting to the meter from the mounting device must use sufficient insulation for the service voltage employed. As a general rule insulation should be designed for a 480 volt ACrms service voltage since service voltage is not always known at the time of meter manufacture. Warning All applicable electrical codes and standards must be followed. Failure to use sufficient insulation on option or I/O cables connecting to the meter through the mounting device could cause serious personal injury, property damage, and/or death.

1

1. Introduction to the S4 and the S4e

1.1 The S4 and the S4e

The S4 and S4e solid-state meters provide a single solution for nearly all metering applications. The S4 combines the time-proven technology of Landis+Gyr‘s previous solid-state meters with enhancements, including wide-dynamic voltage ranging, forms consolidation, GyrBox site diagnostics, and ServiceScan automatic meter service type recognition. Key S4e enhancements over the S4 are:

Flash memory – field programmable firmware

Protects customer investment - allows fixes, upgrades and feature enhancements

ANSI tables or DGCOM firmware available

AMR module friendly – largest space for integrated solutions

Transformer Loss Compensation (ANSI only)

On board 128K load profile option

Differences between the ANSI and DGCOM protocols are explicitly stated in this manual. S4 is used throughout this manual to refer to both the S4 and S4e meter unless otherwise stated.

Figure 1.1 S4 Meter

The S4 provides more than just reliability and accurate billing data. The S4 is designed to be a building block for a complete metering system. See section 1.7 for communication options and section 1.5 for upgradeability. Combining the S4 with the ProView32 software package yields a complete system for real-time voltage, current, and load data monitoring; user-defined event alerts; graphical load analysis capability; and vector diagrams.

2

1.2 The S4 Meter Family

All S4 meters include wide-dynamic voltage application capability, forms reduction, ServiceScan automatic service recognition, and GyrBox installation diagnostics and monitoring. (Note: GyrBox is not available in the AXL meter line.) Each register type is available with either the DGCOM firmware or with the ANSI protocol, with the exception of the AXL, which does not have full communication abilities unless it is upgraded to an AXS4. The following chart details the various register types available for the S4 and S4e meters:

AXLS4: Active Energy (kWh) only, Factory Pre-Programmed.

Upgradeable to AXS4

AXS4: Adds Active Demand. TOU Capabilities with battery installation. Load Profile Capable. Software Programmable.

Upgradeable to RXS4

RXS4: Adds Reactive Energy and Demand with Selectable Reactive Metrics.

Downgradeable to AXS4

1.3 ServiceScan Automatic Meter Service Type Recognition

Wide-dynamic voltage ranging and form consolidation techniques allow each S4 to be used in a wide variety of metering installations. There is no need, however, to identify the service in advance. You can simply install the S4, and it will automatically detect the service type and voltage, displaying the information on the LCD and properly configuring the GyrBox for a complete diagnostic check of the installation. An S4 can be re-installed at an installation of a different wiring type, same base type required, without the need for re-programming. For use in a non-ANSI standard service, a user defined service type can be downloaded to the S4, (see section 3.2.3).

1.4 GyrBox Installation Diagnostics

The S4 GyrBox continually performs a complete diagnostic analysis on the metering installation equipment, the service wiring, and the load characteristics. See section 5.2 for instructions on activating GyrBox mode. The S4 continually monitors the service and load for equipment failures, improper installation wiring, poor load conditions, power quality conditions, tampering. GyrBox monitors the installation for phase polarity, inactive phases, phase angle displacement, phase imbalance, and energy flow polarity while reporting in real-time the phase angles, phase voltages, phase currents, and diagnostic error counters.

1.5 Software and Software Upgrades

The S4 meter offers flexible upgrade and downgrade options to support today‘s rapidly changing utility environment. ProPak is Landis+Gyr‘s upgrade utility and has the ability to upgrade AXL and AX meters to reactive, upgrade load profile and upgrade the flash firmware (only in S4e). Upgrades require a connection to the meter and a hardlock key (USB or Parallel Port models available). The meter programming utilities are 1132Com for reading and programming and 1132Prog for developing programs. Windows 98 SE, Windows 2000 or Windows XP is needed for 1132Com/1132Prog. For DOS-based PC‘s Landis+Gyr offers, on request, DG1100 which offers a similar look and feel to 1132Com/1132Prog and has limited upgrade features similar to ProPak. Note: DG1100 is no longer supported and newer meter and updates may not work properly using DG1100.

3

1.6 Inputs / Outputs

An optional input/output board provides up to four, form C, solid-state relays and up to two external inputs for recording pulses from a remote source. See section 8 for more information. The board can be easily added in the field without the need for special tools or soldering.

4

Figure 1.6 Option Board

1.7 Communications

The modular S4 meter package is designed to allow for the maximum flexibility to add functionality in the future, leaving space for communications boards as well as advanced function processing boards and input/output relay boards. Communications boards, such as the internal telephone modem, RS485 or RS232 boards can be supplied with the meter from the factory or easily added to a meter in the field. In addition several AMR third party vendors offer various automated meter reading options.

1.8 Advanced Feature Sets

1.8.1 Expanded Load Profile of 32K or 128K Bytes

Using the AXRS4 or RXRS4, a utility has the capability of recording up to 15 channels of load profile information with 32K (normally used for 1 channel recording) or 128K bytes of memory for conducting power quality load surveys. The load profile capability in conjunction with Landis+Gyr Data Analysis Software (DG1150) provides utilities and their customers with a graphic representation of load conditions for continuous monitoring of the power system. See section 7.10 for a full discussion on load profile capabilities.

5

2. Application Information

2.1 Available Meter Forms by Base and Class

Base Transformer Rated Class 20

Class 120 Class 200 Class 320** Class 480

S-Base 3, 9/8, 45(5)*, 36(6)*, 29, 56

2, 12, 25, 16/15/14

2, 12, 16/15/14

A-Base 10/8, 45(5)*, 36(6)* 16/15/14

K-Base 12, 16/15/14, and 27

*36S/36A replaces the traditional 6S/6A, 45S/45A replaces the traditional 5S/5A **Class 320 Meters are referred to as SE base

36S 6S

5S 45S

Figure 2.1 Wiring Diagrams for 36S (6S), 45S (5S)

2.2 Installation Procedures

For installation instructions refer to local utility practices, regulations and/or the Handbook for Electricity Metering.

6

2.3 Battery Installation (for TOU and Load Profile applications)

Warning: LINE POTENTIAL IS PRESENT ON THE INCOMING CONNECTORS ON THE MEASUREMENT

BOARD INCLUDING THE BATTERY CONNECTOR. BE SURE TO INSTALL THE BATTERY WITH THE METER DE-ENERGIZED.

1) Remove the meter cover or battery hatch

2) Place the battery‘s two-pin connector into the matching two-pin slot, which is located in the six o‘clock position on the register assembly housing, see figure 2.3 on the next page

3) Put the battery in the round cavity

4) Position the battery wires into the cavity to prevent them from interfering with cover installation or meter functions

5) Replace meter cover or battery hatch

Figure 2.3 Battery Installation Procedures

2.3.1 Battery Carryover Time

Battery carryover time is measured to log the cumulative time the battery has been in use. Time on carryover is displayed in minutes, and is reset to zero when a new battery is installed and the change battery function is performed in 1132Com. Minimum expected carryover time for the RXS4 meter with supplied battery is 2 years. The shelf life of the battery is 10 years.

7

3. Operating Instructions

3.1 Overview of Electronic Hardware

3.1.1 LCD Display

A full listing of the Register Displays is found in Appendix B. The arrow indicates direction of positive energy flow.

Figure 3.1.1 LCD Display

The potential indicators on the LCD (Va, Vb, Vc) appear only if the service is polyphase and only then if potential is applied to the respective phase. The annunciators, kVARh, Vrms, kW, etc. are programmed for display using 1132Prog/1132Com. They can be enabled or disabled; this feature does not affect the other indicators/identifiers on the LCD. The nominal service voltage indicators (120, 240, 277, 480) will signal which service voltage is being applied to the meter. Review of the power quadrant indicator tells us the quadrant in which power is presently applied by flashing that particular quadrant. The delta/wye will light according to the service type of the meter. The digital power indicator scrolls across the bottom of the display (left to right) to indicate positive or (right to left) to indicate negative energy flow.

Potential indicators

Delta/Wye

Nominal service voltage

Power quadrant indicators Digital Power Indicator

Annunciators

8

3.1.2 Diagram of Parts

Figure 3.1.2 Exploded Diagram of S4

9

3.1.3 Switches

There are three visible switches on the S4: one for Demand Reset, one for scrolling the display and one for Test Mode. Only the Demand Reset switch is accessible through the cover. To activate the Test Mode switch and manually scroll, the cover must be removed.

Figure 3.1.3 S4 Switches

Reed Switch

A reed switch, which is activated by placing a magnet at the twelve o‘clock position (on top of the meter), can be used for entering the alternate display sequence, with a swipe, and activating the GyrBox diagnostic displays, by holding the magnet at this position.

3.1.4 Optical Port/ Calibration LED

An optical port is provided for programming and recording meter data. The port is an ANSI Type II. The optical port and calibration output share the same LED. Whenever the meter is not communicating, the LED will pulse at a rate proportional to the watthours flowing through the meter. Other programmed metrics can be tested by entering test mode, manually scrolling to the appropriate metric calibration pulse display (causing the LED to pulse proportional to that metric), and checking calibration while in test mode. The Calibration LED stops after 24 hours. In an S4 it restarts after a power fail and when entering test mode, in an S4e it restarts when any switch is activated.

Reset

Test Mode Scroll

Reed Switch Location

10

3.1.5 Programmable Outputs/Inputs

Up to four programmable outputs and two programmable inputs are available, see section 8.

3.2 Initial Power-Up and Operation

Unless specified by the customer, AX and RX meters are shipped unprogrammed. AXL meters, however, are kWh meters and are always shipped programmed. When powered up, the display on an unprogrammed device will show Error Code 000010, indicating an unprogrammed state. To clear this condition, the device needs to be programmed using 1132Com (Landis+Gyr‘s Reader/Programmer Software package) through an optical serial communications cable or equivalent communication device. An unprogrammed S4 will accumulate billing data, including kWh and kW in 15-minute blocks but cannot be read using 1132Com. An S4 is always a demand meter in an unprogrammed state.

3.2.1 Unprogrammed Displays

Upon powering up, an unprogrammed register goes through a catch-up period, auto-scrolls through a power-up display sequence, then stops on the error code(s). The unprogrammed displays are as follows:

ID Display Mode

All Characters Segment Check – All LCD Characters Lit Normal

AXD, AX, RXR, Etc. Firmware Revision of Microprocessor Normal

DSP Firmware Revision of Digital Signal Processor Normal

TOT Total kWh Normal

MAX Maximum kW Normal

BAT Time on Battery Normal

ERR Error Code 000010 – Designates unprogrammed meter Normal

FL Full Load as left registration after factory calibration Alternate

LL Light Load as left registration Alternate

PF Power Factor as left registration Alternate

TOT Total kWh Test

MAX Maximum kW Test

CAL Calibration Pulse – kVAh rms Test

CAL Calibration Pulse – kVARh td Test

CAL Calibration Pulse – kVAh td Test

Table 3.2.1 Unprogrammed Displays

3.2.2 Programming Equipment

The S4 registers are programmable using 1132Prog/1132Com for Windows based devices. Third party hand-held readers also have the ability to communicate to the S4. The S4 offers a user-friendly environment for programming the registers. Consult the 1132Prog/1132Com help files for detailed instructions on programming the meter.

11

3.2.3 Manual Loading of Service Type

In installations that are not ANSI standard, such as using a polyphase meter in a single phase application, ServiceScan allows the user to define the voltages and voltage angles to create a new service type. The following values can be programmed:

Voltage (rms) values: 0v, 60v, 104v, 120v, 208v, 240v, 277v, 416v, 480v

Phase angle values (in degrees): 0, 60, 90, 120, 180, 240, 270, 300

3.3 Accessing the Display Modes

Up to 64 individual displays may be selected in any order and can be used more than once. An ANSI firmware version meter counts one display programmed for Normal, Alternate and Test Mode as three different displays while the DGCOM meter counts this display as one. There are four display sequences: Normal, Alternate, Test and GyrBox Diagnostics.

Normal Display Sequence

The Normal Display Sequence is present on the LCD under normal operating conditions if no special action is taken.

Alternate Display Sequence

An alternate display sequence may be created for the LCD using 1132Prog/1132Com software. To activate the alternate display,

1) Place a magnet over the meter in the 12 o‘ clock position for 1 second to activate the reed switch. See section 3.1.3 for a description of the reed switch.

OR

2) Hold the scroll button for between 3 and 6 seconds.

The word ―Alt‖ will appear on the display before the alternate display sequence starts. Alternate displays will only be shown in the Alternate Display Sequence.

To exit

The meter will automatically exit back to the normal display sequence after one pass through the alternate displays.

GyrBox Display Sequence

The GyrBox is a sequence of displays designed to facilitate troubleshooting problems in the meter installation. All normal meter functioning continues while in the GyrBox display sequence. The GyrBox sequence is pre-defined, but GyrBox displays may also be programmed to appear in the other display sequences, i.e., normal, alternate and test mode.

There are three methods for obtaining the GyrBox display sequence:

Reed Switch

1) Activate reed switch for three seconds, the display will go blank briefly, which indicates the beginning of the GyrBox sequence.

12

2) The meter will then show the first GyrBox display.

3) Press the scroll button to stop auto-scrolling.

To exit

1) Remove the magnet to return to the normal sequence.

Scroll/Test Buttons

1) Press the scroll button for at least 6 seconds to get into fast scroll mode, then flip up the test switch while continuing to hold the scroll switch. The display will go blank briefly.

2) Release scroll button after entering the GyrBox display sequence.

Note: The use of the test mode switch in this sequence does not cause the meter to enter test mode.

To exit

1) Flip down the test mode button.

1132Prog/1132Com through the Communication Port

You can view the GyrBox displays using 1132Com by selecting the View Data operation in the read menu. You can select this operation using the following procedure:

1) In 1132Com highlight a meter file in the meter file window on the lefthand side. Selecting ―New Meter‖ will automatically establish a connection to a meter.

2) Select View Data under the read menu. 3) View each screen of data. Use the tabs at the top to move through the

different portions of the meters program and registers, GyrBox Diagnostics and Instantaneous Data are the two GyrBox related tabs.

To exit

1) In 1132Com exiting is performed by selecting the ‗X‘ in the upper right corner of the program or selecting Exit in the File menu.

Test Mode Sequence

Flipping the Test Mode switch enters the Test Mode. ―TEST‖ will appear on the LCD. While in test mode, the displays must be manually scrolled using the scroll switch.

3.4 Scroll Modes

3.4.1 Auto-scroll Mode

The display continually cycles through the programmed Normal Display Sequence, referred to as auto-scrolling. The LCD displays each quantity for a selectable time of 1 to 16 seconds. The auto-scroll mode operates by default and is only affected by a manual activation of another display mode, by activating a switch or by the occurrence of an error that is programmed to stop the auto-scroll sequence. Auto-scrolling is not active in test mode.

13

3.4.2 Manual Scroll Mode

While the S4 register is auto-scrolling, if the scroll switch is momentarily depressed, the display jumps to the first item in the sequence and auto-scrolling will be suspended. Each subsequent press of the scroll button causes the display to show the next item in the sequence. The display resumes auto-scrolling when the switch has not been activated for one minute. Manual scrolling operates in this manner for both the normal, alternate, and GyrBox sequences. The test mode sequence never auto-scrolls.

Note: In Time of Use meters‘ manually scrolling for the first time causes a battery test on TOU meters. If the battery voltage is low, an error code, see section 9.1, is indicated on the meter.

3.4.3 Scrolling in the Alternate Display Sequence

If the scroll switch is held down for more than 3 seconds, the Alternate Display Sequence is initiated, starting with the ALT display then continuing with the first alternate display item. If the scroll switch is held down for more than 6 seconds the fast scroll feature in the Alternate Display Sequence is initiated. The Alternate Mode may also be initiated by waving a magnet over the top of the meter. Once the end of the Alternate Display Sequence is reached (unless it is fast scrolling), the S4 register reverts back to the Normal Display Sequence.

3.4.4 Scrolling in the GyrBox Mode

Once in the GyrBox sequence (entered via the reed switch or the button combination), the GyrBox displays auto-scroll. Pushing the scroll switch for the first time stops the auto-scrolling and the S4 will be in the manual scroll mode starting with the first GyrBox display. Unlike the alternate display sequence, which just makes one pass before returning to the normal sequence, the GyrBox sequence wraps around to its first display and continues scrolling until GyrBox mode is exited. Either de-activating the reed switch or placing the test mode switch in the off position exits GyrBox, depending on the method of activation.

14

4. Test Mode Test Mode feature allows meter testing without affecting billing data, data collected is for test mode purposes only. Test mode is entered through the optic port or by activating the test mode switch on the face of the device. The register may be read while in test mode, but may not be programmed.

4.1 Test Mode Display

Pressing the display scroll switch causes the next item to be displayed. Each test mode display value is updated continuously.

4.2 Actions upon Entering Test Mode

Upon entering test mode, the current demand interval is terminated and all billing data is stored. As a result, this demand interval will be shorter than normal. The end-of-interval (EOI) output and display indicator both activate as if a normal EOI has occurred. If the present demand is greater than the previous maximum demand, maximum demand will be updated.

4.3 Action upon Exiting Test Mode

Upon exiting test mode all billing data is restored and a new demand interval is started. The EOI output switch and display indicator activates, indicating the end of test mode and the start of a new demand interval and subinterval.

4.4 Test Mode Demand Functions

1132Prog/1132Com allows programming of separate demand interval length and Kh for test mode purposes. This allows for quicker verification of demand by using a shorter interval. Using a large Kh value allows display of kWh on the LCD with small accumulation. A demand reset performed in test mode starts a new test mode interval and zeroes accumulated demand, maximum demand, and the number of register pulses recorded.

4.5 Operation of Outputs during Test Mode

While the meter is in test mode, the optional outputs work as they would in normal mode, with the following exceptions:

EOI activates upon entering and upon exiting test mode and with every EOI.

Demand Threshold Alert (DTA), Voltage Threshold Alert (VTA) and Power Factor Threshold Alert (PFTA) are cleared upon exiting test mode.

Load Control will not work in test mode.

4.6 Miscellaneous Functions During Test Mode

Power on demand delay (PODT) is not in effect during test mode, although timing continues. For example, if PODT is 10 minutes and the meter is put into test mode for 4 minutes immediately on power up, the meter will start accumulating demand 6 minutes after exiting Test Mode.

15

4.7 Test Mode Time-out

After a prescribed length of time, the test mode is automatically ended and the meter returns to normal mode. 1132Prog allows the user to program the test mode time-out value from 1 to 255 minutes (a value of 0 disables the time-out function) into the meter. Once test mode is entered, the test mode counter begins timing. If the meter is left in test mode longer than the time-out value, test mode will end. If any switch closure or optical communication occurs while in test mode, the time-out counter will restart counting at zero.

Note: If a meter leaves test mode due to inactivity time-out and the mechanical switch stays activated for longer than 4 minutes, the stuck switch error, if programmed, will be displayed. This error will be cleared after the switch is deactivated.

16

5. GyrBox Operation

5.1 Overview of GyrBox

GyrBox diagnostics are designed to quickly conduct a meter and installation system electrical check. The S4 GyrBox continually performs a complete diagnostic analysis on the metering installation equipment, the service wiring, and the load characteristics. This allows the S4 to continually monitor the service and load for equipment failures, improper installation wiring, poor load conditions, power quality conditions, and tampering. The GyrBox monitors the installation for phase polarity, inactive phases, phase angle displacement, phase imbalance, and energy flow polarity.

The voltage and current per phase information that the meter automatically calculates and displays will indicate if the meter is installed and operating properly. Continuous voltage and current measurements are rms values and are updated every 5 seconds.

Each time a diagnostic error is detected, a Remote Communications Alert will be executed. If the optional modem is installed, then it will call in the error if it is programmed to do so.

5.1.1 ServiceScan: Service Recognition and Verification

ServiceScan automatically detects the service type and voltage, displaying the information on the LCD and properly configuring the GyrBox for a complete diagnostic check of the installation. This feature checks if the service matches the meter form type, i.e., a 8/9S meter form will not function as a 6S meter form. In cases where all three potentials are not initially present when the meter first powers up (e.g. installing a meter in a 480V site), ServiceScan will not be able to identify the service at first and will then rescan the voltage and phase information every minute until correctly identifying the service type. Therefore, an S4 can be re-installed as a different type without needing to be re-programmed.

For all S4 meters, ServiceScan is performed at power up. Starting with firmware version 3.07, ServiceScan is performed not only at power up but also in one minute intervals following power up until the device recognizes a valid service.

Refer to Appendix C entitled ―Service Types‖ for a table listing various devices and their compatible service types.

5.1.2 Service Scan Displays

A 120V four wire wye service will illuminate the ―Y‖ annunciator, the ―120‖ nominal service voltage, and the three potential indicators (―Va, Vb and Vc‖).

A 240V four wire delta service will illuminate the ― ―, the ―240‖ nominal service voltage (even

though the phases individually measured line to neutral would be 120, 120 and 208), and the three potential indicators.

For single phase loads on test boards, only the nominal voltage will be illuminated. Meters with firmware versions prior to 3.10 do not distinguish between 240V and 277V. In both cases the 277V annunciator will be illuminated.

17

5.1.3 Programmable Service Types

The GyrBox accommodates these service types: network, 3 wire delta, 4 wire wye, and 4 wire delta. Non-standard service types can be programmed using 1132Com.

5.1.4 GyrBox Activation

GyrBox may be activated while the register is operating in either the normal or alternate mode of operation. Normal energy measurement continues while GyrBox is activated.

5.2 Methods for entering GyrBox

There are two ways of entering GyrBox:

Reed Switch (see section 3.1.3)

1) Place a magnet on top of the meter in the 12 o‘clock position.

2) After three seconds, the display will go blank briefly.

3) The meter will then show the first GyrBox diagnostic.

4) Press the scroll button to stop auto-scrolling.

To exit

1) Remove the magnet to return to the normal sequence.

Scroll/Test Buttons

1) Press the scroll button for at least 6 seconds to get into fast scroll mode.

2) Flip up the test mode lever to put the S4 into the GyrBox after the brief blanking of the LCD. The test mode button used in this fashion will not light up the TEST MODE indicator since meter operation is not affected by the GyrBox display sequence.

3) After entering the GyrBox sequence, release the scroll button.

To exit

1) Flip down the test mode button.

18

5.2.1 Digital Power Indicator (DPI) during GyrBox Activation

The DPI shows the direction of energy flow during each phase check. It runs at a constant rate in the direction of the energy flow.

5.2.2 Display Format and Reference

The phase information is displayed with no leading zeros and one fixed decimal point. The diagnostic counters are displayed with no leading zeroes, similar to the following example:

Figure 5.2.2 Sample GyrBox Display on LCD

The meter sets the ―A‖ phase voltage phasor to 0.0° and calculates all other voltage and

current phasors with relation to phase ―A‖ voltage. Thus, phase ―A‖ voltage angle will always be displayed as 0.0. The displayed value is based upon a long-term average. The current angle calculations also use Phase A as a reference, and are based upon the following relationship:

tan 1 Var

Watt

Quadrant of the angle is based upon the polarity of watt and Var.

19

5.2.3 GyrBox Display List

The GyrBox scrolls through the following set of diagnostic items/counters:

Description Indicator Display Format

Suffix

Phase ―A‖ Voltage Angle PhA 0.0° V

Phase ―A‖ Voltage PhA xxx.x Vrms

Phase ―A‖ Current Angle PhA xxx.x° I

Phase ―A‖ Current PhA xxx.x Irms

Phase ―B‖ Voltage Angle PhB xxx.x° V

Phase ―B‖ Voltage PhB xxx.x Vrms

Phase ―B‖ Current Angle PhB xxx.x° I

Phase ―B‖ Current PhB xxx.x Irms

Phase ―C‖ Voltage Angle PhC xxx.x° V

Phase ―C‖ Voltage PhC xxx.x Vrms

Phase ―C‖ Current Angle PhC xxx.x° I

Phase ―C‖ Current PhC xxx.x Irms

Number of Diagnostic 1 Errors D1 xxxxx







Table 5.2.1 GyrBox Displays

Note: Phases that are unused will still show up in the GyrBox display list.

20

5.2.4 Diagnostic Counters

The GyrBox diagnostic counters record the number of times (0 to 65535) that a diagnostic error was detected since the last counter reset. Any diagnostic conditions still existing when the counters are cleared will count to 1 within 15 seconds. You can clear the diagnostic counters by performing a cold start, either manually or optically, or a demand reset.

5.2.5 Diagnostic Check Display Options

The following section lists the possible display formats for diagnostic errors. Each diagnostic error can be programmed for display in one of these formats.

Note: The meter must pass two consecutive checks before the diagnostic error will be cleared from the LCD.

Lock: The selected error remains on the LCD display. The diagnostic display causes auto-scrolling to stop at the Error Code 1 display. Diagnostic check code displays appear at the end of the normal/alternate scroll sequence just before Error Code 2 and Error Code 1 (See Section 9 for a discussion of Error Codes).

Scroll: The diagnostic error does not cause auto-scrolling to stop. The error code byte is inserted at the end of the display sequence.

No Display: The diagnostic error is not displayed on the LCD. The diagnostic counter is still increased by one.

Disable: The diagnostic error will not be displayed on the LCD and the diagnostic counter will not be increased.

5.3 Diagnostic Checks

The following sections describe each of the diagnostics that GyrBox performs. When a diagnostic check is triggered it will appear on the normal display sequence if it has been programmed to lock or scroll. After seeing the particular diagnostic error in the LCD display, compare the Phase A, B and C readings to the expected values found in section 5.4. Note which values are inconsistent and use that information to help track down the source of the error.

5.3.1 D1 (Polarity and Cross-phase)

The D1 diagnostic checks for proper phase relationships of voltage, incorrect polarity of voltage, internal meter measurement malfunction, and faulty site wiring. The envelope of the voltage phasors is fixed at ± 10 . If the voltage phasor values measure more than ± 10 from their

nominal position, an error will be detected. This check is not performed when phase A voltage is missing.

21

5.3.2 D2 (Phase Voltage Deviation Check)

The Phase Voltage Deviation Check verifies loss of phase voltage, incorrect phase voltage, shorted voltage transformer windings, or incorrect voltage transformer ratio by detecting differences between phase voltage magnitudes. This check uses the nominal voltage per phase as a reference. The tolerance range of the voltage deviation (%) is programmable using 1132Prog/1132Com software.

5.3.3 D3 (Inactive Phase Current Check)

The Inactive Phase Current Check verifies that the service is maintaining an acceptable current level and is expected to detect current diversion and an open or shorted CT circuit. The low current value is programmed into the register using 1132Prog/1132Com software and will have a limit starting at the creep level of the meter and up to 200A in increments of 1mA. Each phase can have a separate threshold. The error flag will trip if one or more currents fall below its threshold and at least one current remains above this value for more than 15 seconds. The error flag will not trip if all phase currents fall below their thresholds.

5.3.4 D4 (Phase Angle Displacement Check)

The Phase Angle Displacement Check diagnostic verifies that the elements are sensing and receiving the correct current for each phase of the service and indicates poor load power factor system conditions and reversed CT‘s. The phase displacement angle ( ) is programmable

through the 1132Prog/1132Com software package. Angles for leading and lagging loads are separately programmable. The current phasors must be within this programmable phase with respect to their voltage phasor to pass this diagnostic check. This is calculated with respect to its respective voltage phasor, not necessarily phase A‘s voltage phasor. The check is not performed if Diagnostic #3 did not pass or if phase A voltage is missing.

5.3.5 D5 (Future)

This diagnostic is reserved for future use.

5.3.6 D6 (Current Magnitude Imbalance Check)

This diagnostic compares the current of each phase with the other phases in the installation. If the ratio between any phase current and the average of all phase currents exceeds the user programmable percentage, then this diagnostic flag is tripped. The check is not performed if Diagnostic #3 did not pass, if the average current is below 0.5% of class, or if phase A voltage is missing.

5.3.7 D7 (Energy Polarity Check)

The D7 diagnostic checks for reverse energy flow of one or more phases. If the energy polarity (watts) for any phase is negative, this flag will be tripped. This check is not performed if phase A voltage is missing.

22

5.4 Normal phase angles

The following charts outline the ideal voltage phase and current phase angles. Phase and current voltages will depend upon the application.

5.4.1 3-Wire Network Service

45S (5S)--Unity power factor with load connected line to neutral

Phase A (Left) Phase B (Center) Phase C (Right)

Voltage Angles 0 N/A 240

Current Angles 0 N/A 240

0180

270

90

Va

240

120

Vc

Ic

Ia

12S--Unity power factor with load connected line to neutral




0 180

270

90

Va

240

120

Vc

Ic

Ia

23

5.4.2 3-Wire Delta Service

45S (5S)




0180

270

90

Va

Ic

Vc

Ia

300

30

12S




0180

270

90

Va

Ic

Vc

Ia

300

30

24

5.4.3 4-Wire Wye Service

36S (6S)--Unity power factor with load connected line to neutral


Voltage Angles 0 120 / N/A* 240

Current Angles 0 120 240

*For devices with firmware versions older than 3.07, the voltage phase angles for phase B are N/A.

0180

270

90

240

120

Vc

Ic

Va

Ia

Ib

Vb

9S/8S--Unity power factor with load connected line to neutral


Voltage Angles 0 120 240


0180

270

90

240

120

Vc

Ic

Va

Ia

Ib

Vb

25

16/15/14S--Unity power factor with load connected phase to neutral




0180

270

90

240

120

Vc

Ic

Va

Ia

Ib

Vb

26

5.4.4 4-Wire Delta Service

45S (5S)--Unity power factor with balanced loading




0

270

90

Va

Ic

Vc

Ia

9S/8S--Unity power factor with balanced loading




0180

270

90

Va

Ic

Vc

150 30

Vb

IaIb

27

16/15/14S--Unity power factor with balanced loading




0180

270

90

Va

Ic

Vc

150 30

Vb

IaIb

28

5.5 Common sources for diagnostic alerts

The following section outlines the most common causes for the diagnostic alerts. All of the examples are based on a 120 Volt, 4 wire wye, 9S/8S application. The following examples are sorted by the diagnostics that are triggered for each possible problem. Each example lists the cause of the problem and the voltage, voltage angle, current angle, and current values shown for each phase as a result of this problem. The values that change for each phase as a result of a problem are listed in bold in each table. Fields marked float designate that the value isn‘t constant.

Diagnostic #

Possible Problem

1 and 2 Loss of potential on any phase.

Normal GyrBox Displays

Phase A Phase B Phase C

Voltage Angle 0.0 120 240

Voltage 120V 120V 120V

Current Angle 0.0 120 240

Current 2.5A 2.5A 2.5A

Phase A voltage is missing


Voltage Angle 0.0 floats floats

Voltage 0.0V 120V 120V

Current Angle 0.0 floats floats


Phase B voltage is missing


Voltage Angle 0.0 floats 240

Voltage 120V 0.0V 120V

Current Angle 0.0 floats 240


Phase C voltage is missing

This situation powers down the meter.

29

Diagnostic #s

Possible Problem

4 and 7 CT‘s are reversed. The current is flowing in the wrong direction.

Normal GyrBox Displays (resistive loads)

PF = 1.0rms/1.0td; Total Watts = 900






Phase A current is reversed







Phase B current reversed







Phase C current reversed







30

Phase A and B reversed

PF = 0.333rms/1.0td; Total Watts = -300






Phase A and C Current Reversed







Phase A, B and C Current Reversed





Current Angle 180 300 60


31

Diagnostic #s

Possible Problem

4, 7, and sometimes 1

Potential transformer reversed.

Normal GyrBox Displays (resistive loads)






Phase A voltage reversed: Diagnostic # 1, 4, 7







Phase B voltage reversed: Diagnostic # 1, 4, 7







Phase C voltage reversed: Diagnostic # 1, 4, 7







32

Phase A and B voltage reversed: Diagnostic # 1, 4, 7

PF = 0.333rms/-1.0td; Total Watts = -300






Phase A and C voltage reversed: Diagnostic # 1, 4, 7







Phase B and C voltage reversed: Diagnostic # 1, 4, 7







All Voltages Reversed: Diagnostic # 4, 7 (not 1)







33

6. Demand Metering The RXS4 meter can calculate active (kWh) energy or reactive (VARtd, VAtd, VArms) energy and demand in block, rolling block, or thermal emulation. Demand interval length and the number of subintervals are established through programming. The possible arrangements of subintervals per interval for ―rolling demand‖ are shown in Table 6.0. Rolling demand is sometimes referred to as ―sliding demand‖. A new demand interval timing sequence begins when power is applied/restored, upon programming when the demand interval is changed, and when entering or exiting test mode. The number of minutes remaining in the current subinterval is available for display.

Number of Subintervals

Interval 1 2 3 4 5 6 10 12 15

Length Demand Subinterval Length (minutes)

1

5

10

15

30

60

1

5

10

15

30

60

-

-

5

-

15

30

-

-

-

5

10

20

-

-

-

-

-

15

-

1

2

3

6

12

-

-

-

-

5

10

-

-

1

-

3

6

-

-

-

-

-

5

-

-

-

1

2

4

Table 6.0 Demand Subintervals/Intervals

6.1 DEMAND TYPES

Demand can be displayed in three different ways:

Maximum (Indicating) demand: The maximum since the last demand reset.

Cumulative demand: The sum of the maximum demands from all demand resets.

Continuous cumulative demand: The sum of indicating and cumulative demands.

Note: The user must choose either cumulative or continuous cumulative demand displays.

6.1.1 Thermal Demand

Thermal Demand is the logarithmic average of power used, which means that least recent load is weighed more heavily than most recent load. Thermal Demand is an alternate method to block and rolling block demand in Demand Only meters. Because Thermal Demand is the logarithmic average, Thermal Demand is not reset to 0 on a rate change or a Demand Reset. Thermal Demand is unaffected by a rate change. On a Demand Reset, Present Demand becomes the new Maximum Demand.

See the Handbook for Electricity Metering for a more complete discussion of Thermal Demand metering.

34

6.1.2 Five Highest Demands

The highest five demands during a billing period are recorded with the time and date of occurrence. Windowed Demand, or Demand Peak Window, provides another way to record the five highest demands. With windowed demand, a minimum time window separates the highest peaks in time. This window of time can be selected in length to be zero, 1 hour or 4 hours. If zero is selected, the five highest demands are separated by the programmed demand interval length.

6.2 Demand (Billing Period) Reset

Block: The following actions occur upon Demand Reset:

1) For each of the rates the following is done to the present season values:

a) Max kW is added to the Cumulative kW value and Max kM (kM is the metric selected: VARtd, VAtd, or VArms) is added to the Cumulative kM value.

b) Max kW is reset to zero. Max kM is reset to Zero.

2) The five highest kW and kM values and coincident values are reset to zero (TOU Only).

3) For block demand, all demand data for all previous intervals is zeroed, and all demand data in the present interval (including before the Demand Reset) is retained.

4) Date of last reset is updated (TOU Only) (see exception under No. 5).

5) If it is an automatic Demand Reset as a result of season change, then all present season values are written to last season registers before any data is zeroed. Date of last reset is not updated.

6) If a season change results from this Demand Reset, then all present season values are written to last season registers before any data is zeroed.

Rolling, Demand Reset Type I

Same as Block Demand Reset except demand data from current subinterval is not cleared. As a result the Present kW register is not affected.

Rolling, Demand Reset Type II

Same as Block Demand Reset except all demand data from all previous subintervals is zeroed, and all demand data in the present subinterval (including before the Demand Reset) is retained.

Thermal

For each of the rates the following is done to the present season values:

1) Max kW is added to the Cumulative kW value and Max kM is added to the Cumulative kM value.

2) Max kW is reset to present demand. Max kM is reset to present kM.

All present demand data is retained.

If a season change results from this Demand Reset, then all present season values are written to last season registers before any data is zeroed.

35

6.2.1 Automatic Demand Reset upon Season Change

A demand reset may be programmed to occur automatically at each season change. In order to not lose the demand data, all present season demand values are copied into last season demand registers, before clearing the present season values to zero. The last season values can be displayed and can be read by any compatible reader.

6.2.2 Season Change upon Demand Reset

Season Changes may be programmed to occur upon the first demand reset that occurs after the programmed season change date. This feature cannot be programmed simultaneously with "Automatic Demand Reset upon Season Change."

6.2.3 Demand Reset Methods

Manual Method

A Demand Reset can be initiated manually via the reset mechanism installed in the front of the meter cover. Upon initiating a Demand Reset, all LCD display segments are briefly displayed. No further Demand Resets are allowed to occur until the completion of one normal display sequence. After a Demand Reset, the display sequence will begin at the first programmed display of the normal display sequence.

Software Method

A Demand Reset may also be accomplished optically or remotely (via modem, RS232, or RS485) using Landis+Gyr‘s 1132Prog/1132Com software package on a PC or other compatible device. The meter is also capable of automatically doing a demand reset daily, monthly or on season change.

6.2.4 Power on demand delay timing

Power on demand delay timing (PODT) allows for demand measurement to be delayed when power is restored after a power outage. The length of time for which demand is delayed after power resumes is programmable. The demand measurement may be delayed for times of 0 to 255 minutes. A time of zero minutes would cause no delay to occur. The value of PODT left is available for display. Additionally, in a TOU meter a PODT Trigger can be set to designate how long an outage has to be for the meter to utilize the PODT. This value can be programmed from 0 to 255 in minutes and from 0 to 59 in seconds.

36

7. TOU Metering This section of the instruction manual covers the Time of Use function and operation of the AXS4 and RXS4 meters equipped with TOU and recorder capabilities on load profile meters.

7.1 Main Clock

The S4 register maintains its clock by counting the line cycles. The clock maintains accurate time-keeping from the line while power is present. On battery carry over, the S4 register maintains its clock using a 32kHz crystal with an accuracy of ±0.02% per month. Optionally, the S4 may be programmed to always maintain its clock from the 32kHz crystal.

7.2 Time Display Format

The register clock displays time in a 24-hour format of XX hour and XX minutes or with XX seconds. Midnight is considered to be the beginning of a day and is displayed as 00:00 or 00:00.00 with seconds.

7.3 Date Display Format

The S4 can be programmed to display the date in month/day/year, day/month/year, year/day/month or year/month/day (Canada) format. When the year reaches 99, it will roll over to 00 on the following year. The time and date are always stored in the same manner. The format only affects the display of the data.

7.4 Date and Time Setting

Changing the software clock is achievable through any compatible programmer such as a handheld device or a PC with the proper software and hardware without prior knowledge of the program in the meter. Changing the time in the meter will not result in a loss of register data.

7.5 Daylight Savings Time

Daylight savings time shifts either follow U.S./Canada dates or user programmed dates. On a spring time shift the time moves from 2 to 3 AM and from 2 to 1 AM on a fall time shift. In the following table Rate A is programmed from 12 to 1:30 AM and Rate B is programmed from 1:30 AM to end of day.

Event Action

Time reaches midnight Rate A activated

Time reaches 1:30 AM Rate B activated

Time reaches 2:00 AM Time changed to 1:00 (on Fall DST date), Rate A activated

Time reaches 1:30 AM again Time reaches 2:00 AM again

Rate B activated No action

37

7.6 Time On Carryover

Time on battery carryover is measured to log the cumulative time the battery has been in use. Time on carryover is measured in seconds, has an internal capacity of 136 years, and is displayed on the LCD in minutes. Performing a cold start resets the time on battery carryover. Time on carryover will roll over to 000000 when battery usage extends past 999999 minutes (694 days) on the display. Time on battery is available for display. While minutes are available for display, the internal resolution of Time on carryover is seconds.

7.7 Programmable Dates and Schedules

7.7.1 Programmable Dates

The register has enough memory to provide a 20 year calendar when using 15 holiday or season change dates. Users may define their own fixed date perpetual dates. Perpetual dates also signal season changes or holidays. Examples of perpetual dates are:

Jan. 1 New Year's Day

July 1 Canada Day

July 4 Independence Day

Nov. 11 Veteran's Day

Dec. 25 Christmas Day

Dec. 31 New Year's Eve

7.7.2 Seasonal Rate Changes

TOU schedules for up to four seasons per year are available. Seasonal rate changes occur at the first hour of programmable dates (midnight) or at the next reset, if the season change by reset option is selected. At season change, all energy and demand accumulators are copied into last season storage.

A seasonal rate change can be made to occur before the scheduled date via the communications port. One such change can occur per season. This optical command will cause the register to look ahead in its date table and change the season to the next season that is listed there. No other season changes will be allowed until the scheduled season change date is reached.

7.7.3 TOU Daily Schedules

Two hundred and forty transitions are available to divide between the daily schedules. The switch points are shared among the four TOU rates and the optional TOU Load Control switch.

7.7.4 Day Select for Schedules

Each of the seven days of the week may have one of the TOU schedules assigned to it. Any schedule may be used as an exception to the TOU daily schedule (i.e. a holiday).

38

7.8 Load Control/TOU Switchpoints

A switchpoint is a quarter-hour boundary during the day that defines a TOU rate change and/or a programmable output option change. TOU schedules are made up of switchpoints. Each schedule may have from 1 to 96 switchpoints.

The meter allows for up to five TOU rate periods, Rates A, B, C, D and E. Any rate may last for as short as one switchpoint (changing every quarter-hour) or for as long as an entire day. Switchpoints may also be used to enable or disable programmable outputs. Control of the outputs may occur in conjunction with rate changes or apart from them. Therefore, a switchpoint may either change the TOU rate; change the state of the programmable outputs, or both.

The register will handle up to 240 switchpoints (480 bytes). Considering that the schedule definition requires the same space as a switchpoint, and that a schedule may have from 1 to 96 switchpoints, the 480 byte table could hold from 3 to 120 TOU schedules.

Each switchpoint in a TOU schedule may define a load control action as one of its programmable outputs. This action directs the load control relay to energize or de-energize. Energizing a load control relay should close or open the KY contact (depending upon the normal off state of the relay, either open or close). Load control actions in a TOU schedule will have no effect unless one of the optional general purpose relays is programmed for load control.

7.9 Rate Indicator Outputs

Rate indicator outputs may be accomplished by programming an output relay for TOU Load Control as stated in the above section.

7.10 Load Profile

7.10.1 Load Profile Memory Capacity

The S4 RAM sizes are 32K and 128K for the AXR and RXR. The reader/programmer will be able to initialize load profile memory or disable load profile recording completely. On the S4e meter the Load profile is stored on the main board eliminating the need for a daughter board.

The S4 optional recorder is capable of handling 42 days of 15 minute load profile data on four channels with 32K or 42 days of 15-minute load profile data on 15 channels with 128K bytes of memory. The number of days of capacity is dependent upon the interval length duration and the number of channels used. Table 7.10.3 on the following page shows the relationship between capacity and load profile interval length.

7.10.2 Automatic Upgrade/Downgrade of Load Profile Memory

S4 TOU meters, firmware version 3.05 to 4.41, can be field-upgraded to become either an RXRS4 or an AXRS4, respectively. Upgraded TOU meters may later be downgraded to return to their original states (RX or AX functionality).

Upgrading TOU meters simply requires the installation of the SRAM board into the meter. After powering up the meter following the SRAM board installation, the load profile capability will automatically be enabled. All upgraded meters configure the SRAM board to 128k.

39

To downgrade a meter, first reprogram the meter to disable load profile operation, then remove the SRAM board. Failure to first reprogram the meter will result in the creation of a memory error (Error 000100) indicating that the SRAM board is malfunctioning. This error can be cleared by cold starting the meter.

Meters purchased with load profile memory installed at the factory cannot be field-downgraded to remove load profile functionality. Such meters will always expect the load profile memory to be present. As a result, reprogramming cannot clear the memory error you receive if you attempt to field-downgrade such a meter.

S4e meters, firmware versions 6.XX and 7.XX, can be field upgraded using ProPak. The memory can be upgraded from 0K to 128K and downgraded back to 0K.

7.10.3 Load Profile Interval Length

Load Profile interval lengths include, 1, 5, 15, 30 and 60 minutes. Each interval consists of two bytes. The highest order two bits in each interval are used for date/time stamping and even parity indication. 14 bits are left for recording pulses allowing up to 16,383 pulses in an interval. Any pulses received beyond this maximum value will be ignored and the interval will remain at 16,383. The input-pulse scaling factor can be used to scale down high input pulse rates to prevent exceeding the load profile interval capacity. Load profile interval length and TOU demand interval length are independent and may be different.

Number of Days in Load Profile

32 kilobytes of memory 128 kilobytes of data

Interval Length Interval Length

Channels 1 5 15 30 60 1 5 15 30 60

1 11.4 56.7 168.9 334.4 655.4 43.3 216.1 644.0 1274.8 2498.6

2 5.7 28.3 84.5 167.2 327.7 21.7 108.1 322.0 637.4 1249.3

3 3.8 18.9 56.3 111.5 218.5 14.4 72.0 214.7 424.9 832.9

4 2.8 14.2 42.2 83.6 163.8 10.8 54.0 161.0 318.7 624.6

5 2.3 11.3 33.8 66.9 131.1 8.7 43.2 128.8 255.0 499.7

6 1.9 9.4 28.2 55.7 109.2 7.2 36.0 107.3 212.5 416.4

7 1.6 8.1 24.1 47.8 93.6 6.2 30.9 92.0 182.1 356.9

8 1.4 7.1 21.1 41.8 81.9 5.4 27.0 80.5 159.3 312.3

9 1.3 6.3 18.8 37.2 72.8 4.8 24.0 71.6 141.6 277.6

10 1.1 5.7 16.9 33.4 65.5 4.3 21.6 64.4 127.5 249.9

11 1.0 5.2 15.4 30.4 59.6 3.9 19.6 58.5 115.9 227.1

12 0.9 4.7 14.1 27.9 54.6 3.6 18.0 53.7 106.2 208.2

13 0.9 4.4 13.0 25.7 50.4 3.3 16.6 49.5 98.1 192.2

14 0.8 4.0 12.1 23.9 46.8 3.1 15.4 46.0 91.1 178.5

15 0.8 3.8 11.3 22.3 43.7 2.9 14.4 42.9 85.0 166.6

Table 7.10.3 Number of Days in Different Load Profile Configurations

Equation for Number of Days of Storage in Load Profile:

# of Kilobytes * 512 (Intervals/Day+1)*# of Channels

40

plierPulseMultierhourIntervalspPulseCount For DGCOM Calculations For ANSI Calculations

plierPulseMultierhourIntervalspPulseCount

7.10.4 Load Profile Recording Channels

The register records up to 15 channels of load profile data. The number of channels is programmable. The available memory is distributed equally among each channel.

The metric for each load profile channel is selectable by the reader/programmer and may be different from the additional metric used elsewhere in the register for energy and demand calculation. Each channel has a configuration byte defining its selected metric. All calculations are based on the meter‘s true kh. These configuration bytes may be read by the reader/programmer. The metrics available are as follows (all channels must use the same interval timing):

+kWh Ib2h (DGCOM) or Ibh (ANSI)

-kWh Ic2h (DGCOM) or Ich (ANSI)

Lagging VARh (RXR Only) IN2h or INh from neutral current

Leading VARh (RXR Only) External Input 1

Leading Vah (RXR Only External Input 2

VAh rms (RXR Only) Voltage sags per phase

VA2h (DGCOM) or Vah (ANSI) Voltage swells per phase

VB2h (DGCOM) or Vbh (ANSI) Voltage sags any phase

VC2h (DGCOM) or Vch (ANSI) Voltage swells any phase

Ia2h (DGCOM) or Iah (ANSI)

Table 7.10.4 Load Profile Metrics

7.10.5 Load Profile Pulse Values

The pulse count for each interval must be interpreted according to the metric being recorded for that channel. For the energy metrics, e.g. kWh, kVARh, kVAh, each pulse represents one unit of energy equal to the true K factor of the meter (the true Kh/12).

The pulse values for the V2h/Vh and I2h/Ih metrics are internal constants dependent on the service voltage and class of the meter, respectively. Tables 7.10.5.1 and 7.10.5.2 list V2h/Vh and I2h/Ih pulse values, respectively. The ANSI meter stores the metrics as Vh and Ih, while the DGCOM meter stores the metrics as V2h and I2h.

Voltage and current calculations are performed using the following formula:

41

For the voltage sag and swell channels, one pulse is recorded for every 0.3 seconds the voltage is below the load profile sag threshold or above the load profile swell threshold. See table below for pulse multipliers

Voltage Pulse Multipliers (V2h) (S4 and S4e DGCOM)

Pulse Multipliers (Vh) (S4e ANSI)

120 1.0000 0.00833

240 4.0000 0.01666

277 5.3284 0.01923

480 16.0000 0.03332

Table 7.10.5.1 V2h and Vh Pulse Values

Class Pulse Multipliers (I2h) (S4 and S4e DGCOM)

Pulse Multipliers (Ih) (S4e ANSI)

20 0.0278 0.00133

200/320 0.1736 .02344

480 0.1736 .02344

Table 7.10.5.2 I2h and Ih Pulse Values

7.10.6 Load Profile Error Detection

An even parity bit is stored for each load profile interval.

7.10.7 Long Outage Detection

Before a load profile interval has a power outage indicator bit set, the cumulative power outage time during the interval must exceed a programmable length of time. This length of time is programmed in seconds and may range from 1 to 16.

Note: Long outage time for load profile is a different quantity than the long outage time used to trigger demand delay.

A date/time stamp will be added to the load profile memory showing time of power failure and restoration. With these time stamps, the length of power outage may be determined to within 6 seconds. Note: A power fail in load profile is defined as loss of voltage below roughly 85 volts, depending on conditions, for 6 or more line cycles.

7.10.8 Date and Time of Last Load Profile Interval Read

42

The date and time of the last read of Load Profile data will automatically be recorded at the completion of a Load Profile read command. If the reader/programmer needs this date and time, it should be read prior to initiating a Load Profile read command.

7.11 Real Time Billing

Real time billing may be entered via the demand or power factor threshold alerts. Refer to Section 8.2 for real-time communication links.

7.12 Master Reset

A master reset clears all billing data in the register, while leaving the customer program unchanged. The master reset can be performed in two ways: 1) optically using 1132Prog/1132Com software package and 2) manually using the switches located on the display of the register.

Note: Although you cannot cold start an AXL, you can perform a master reset on this device in order to clear billing data.

Performing a master reset optically using 1132Prog/1132Com

Follow the instructions for performing a master reset listed in the help file for 1132Prog/1132Com.

Performing a master reset manually using switches

1) Hold down the reset button on the face of the device.

2) Toggle the test switch up.

3) Release the reset button.

4) Hold down the reset button again.

5) While continuing to hold down the reset button, toggle the test switch down.

7.13 Cold Starts

A cold start will initialize all memory and return the register to an unprogrammed state. The register will accumulate energy and demand data for 15 minute intervals while in this condition. Test mode will not function as normal. You cannot and do not need to cold start an AXL device; however, you can perform a master reset on an AXL in order to clear the billing data as described in Section 7.12 of this manual. If you upgrade an AXL to an AX, you can then cold start it as described below.

Caution: Cold starting a device will result in an irreversible loss of billing data and the meter programmed must be restored.

A cold start may be accomplished in two ways: optically or manually.

7.13.1 Method 1, Optical Cold Start

43

The instructions for performing a cold start can be found in the 1132Com help file.

7.13.2 Method 2, Manual Cold Start

1) Hold the scroll switch for at least 6 seconds to enter fast scroll mode.

2) Release the scroll switch and press and hold the reset switch within 2 seconds. At this point the display will be blank.

3) While still holding reset switch down, within 2 seconds lift and then release the test mode switch.

4) Release the reset switch.

If the steps are not completed correctly and in a timely fashion, ―abort‖ will show on the display. No Cold Start will happen, but a demand reset will occur when the reset switch is pressed.

7.13.3 Register Displays following a Cold Start

After the meter is cold started, the register goes through a catch-up period, auto-scroll through a power-up display sequence and then stops on the error code 000010. The power-up display sequence then is displayed. If you wish to review the power-up display sequence, please consult Section 3.2.1 of this manual entitled ―Power-Up Displays‖.

7.14 ANSI Type II Optical Communications Port

An ANSI Type II optical communications port mounted on the meter cover provides bi-directional communications between the register and an external programmer or reader. To gain access to any optical port functions, the register must first verify a security code. The security code(s) below apply only for the DGCOM meter and can allow three levels of access:

Level 1: Complete access

Level 2: Read and demand reset only

Level 3: Read only

All billing and program information in the register is readable via the optical port. Communications through the optical port is at 9600 baud and is asynchronous. Data transfer is compatible with a PC serial port.

7.15 Security

When the S4 is programmed, a range of security features can be used. The S4 security scheme consists of five levels of access to the meter, involving two communication security codes and a special switch sequence.

44

Once the meter has been programmed, an operator must log in to the meter to establish a security level before any further programming commands or meter operations will be accepted. The security level granted to the operator must be at least as high as the level programmed for the desired operation or the meter rejects the command.

7.15.1 S4 and S4e DGCOM Security Information

The following table shows the requirements for each security level and the operations that can be done at that level. All programming and operational commands (such as Demand Reset) require that the operator log in with a valid L1 or L2 security key. Also, commands protected at L3 security require physical access to the meter in order to perform the L3 override switch sequence. Note that the meter will never accept commands protected at L4 security. A manual cold start is necessary to override L4 security.

Security key required

Switch sequence required

Operations allowed

L0 none none Read commands only

L1 L1 security key none L1 commands

L2 L2 security key none L1 and L2 commands

L3 L2 security key L3 override L1, L2, and L3 commands

L4 N/A N/A Any command

Table 7.15 Security Levels and Corresponding Operations

The L3 override switch sequence consists of either activating the test mode switch or performing the following operation with the Scroll and Reset switches:

1) Press and release the scroll switch.

2) Within 1 second, press and hold the reset switch for approximately 3 seconds.

3) While continuing to hold the reset switch, press and release the scroll switch for a second time.

4) Release the reset switch.

Note: S4 meters with firmware prior to 3.08 support only a subset of the security features. The L1 level is fixed to include the Demand Reset command only, and L4 is not supported. Also, the test mode switch is the only method for performing the L3 override.

7.15.2 S4e ANSI Security Information

These are the five levels of security for S4e meters with the ANSI protocol. Each security code is 20 digits in length and all 20 digits must be used. Each level includes all capabilities of the lower levels:

45

L1 - Allows for the meter to be read only. No programming or procedures may be executed.

L2 - Allows for demand resets to be done.

L3 - Allows for the following additional programming tasks to be performed:

o Set date and time

o Program or modify TOU rates and calendar

o Program or modify the display table

o Program or modify the ANSI specific utility information

o Program or modify the tables associated with modem communication

o Program or modify network ID

o Program or modify output relays

o Program or modify load profile configuration

L4 - Allows for all programming and procedures to be done, with the exception of device configuration.

L5 - Allows everything to be done, including device configuration. This is needed when changing from demand to TOU or back, adding load profile capability or modem capability. It is what is required when altering which ANSI standard tables or Manufacturer tables are enabled in the meter.

7.16 Voltage Quality Information

The S4 continually monitors voltage and provides information for evaluating voltage quality. Through 1132Prog/1132Com, the user can program in voltage sag and swell threshold values (such as 90% and 110%, for example). When the voltage exceeds the sag or swell thresholds, the information is recorded in load profile or communicated via a programmable output.

7.16.1 Sag Information

A threshold value is provided for detecting voltage sags in load profile. If the voltage drops below this threshold, then a sag counter is incremented once per 0.3 seconds. This counter continues to increment until the voltage is no longer less than the sag threshold. At the beginning of each new load profile interval, this counter is zeroed. A load profile channel may be selected to record the value of the sag counter at the end of each load profile interval. Although there is only one sag threshold for load profile, each phase can have its own channel.

7.16.2 Swell Information

A threshold value is provided for detecting voltage swells in load profile. If the voltage exceeds this threshold, then a swell counter is incremented once per 0.3 seconds.. This counter continues to increment until the voltage no longer exceeds the swell threshold. At the

46

beginning of each new load profile interval, this counter is zeroed. A load profile channel may be selected to record the value of the swell counter at the end of each load profile interval. Although there is only one swell threshold for load profile, each phase can have its own channel.

7.16.3 Voltage Sag Alert

A threshold is provided for alerting a voltage sag. The voltage is inspected and an alert set when it drops below the sag alert threshold. This alert is cleared when the voltage is no longer below the sag alert threshold. This threshold is separate from the load profile threshold.

7.16.4 Voltage Swell Alert

A threshold is provided for alerting a voltage swell for output relays. The voltage is inspected and an alert is set when it exceeds the swell alert threshold. This alert is cleared when the voltage is no longer above the swell alert threshold. This threshold is separate from the load profile threshold.

7.16.5 Instantaneous Readings

The following "instantaneous" values are displayable and available through the optical port or the communications link:

Voltage per Phase Current per Phase Neutral Current

kW kVAR* kVArms*

kVAtd* Power Factor* *RX Models Only

These values will be updated at a rate based on the rate of incoming data. The update rate for voltage will be 1 second and for other values the update rate will be no longer than four seconds. On-line updates may vary depending on communications rate and query time.

7.17 Self-Reads

When actuated, the self-read function will save a copy of all energy and demand information, including TOU metrics, and mark the current date and time. Self-read data is available for display on S4 firmware version starting at 4.41. Self-reads are only available in S4 meters with load profile capability and on S4e meters. In addition, a RAM board (catalogue number 69315-1A) is required for self-reads in meters firmware versions below 4.41.

Note: You do not need to have Load Profile functioning for self-reads to work.

7.17.1 Self-Read Data

The following list contains the self-read items that are captured at the time of a self read:

Time Five highest maximum demands

47

Date Current season cumulative demand

Battery carryover time Current season TOU demand data

TOU status Previous season demand data

Previous interval demand Previous season selectable (KM) and 3rd (KM3) metric data (RX)

Previous season TOU data Selectable (KM) and 3rd (KM3) metric data (RX)

Rate bins and total energy Previous season TOU data

Negative energy Five highest maximum demands

7.17.2 Number of Self-Reads

The S4 is capable of storing up to six sets of self-read data. A self-read initiates the transfer of current data into the next available self-read memory block, followed by a demand reset. Only the most recent six self-reads are retained. The oldest self-read is replaced by the most recent when the programmable number has been reached.

7.17.3 Self-Read at Season Change

If a season change and a self-read occur at 00:00:00 of the same day, the self-read actions occur before the season change. Previous season data is stored in the self-read information.

7.17.4 Initiating a Self-Read

You can program an automatic self-read to occur according to the methods listed below. The first three methods (day of the month, hours since the last reset, every day) are mutually exclusive, while the last two methods (after a manual reset and through an external input) can be selected in conjunction with one of the other methods.

A particular day of the month

Self-read occurs on one of the programmable self-read days from 1 to 28 at 00:00:00 on the specified day. Therefore, selecting the first day of the month will actuate self-read at midnight just after the last day of the previous month. Calendar month billing is obtained by selecting the first day of the month as the day which the read should occur.

A particular number of hours since the last reset

Self-read occurs at the specified number of hours following the last demand reset. For example, if the specified number of hours was 5 and the last demand reset was at 12:15:00 of the present day, then a self-read would occur at 17:00:00 and then every five hours thereafter. The range of the number of hours is 0 - 65535, but the most common number of hours is 792 (33 days). This would assure that an automatic self-read would occur only if the normal monthly reading was missed.

Every day

Self-read will occur each night at midnight or 00:00 on the clock.

After a manual reset

48

A self-read occurs after a demand reset is performed using any method except for the demand reset method concurrent with a season change. The self-read data is stored prior to the actual reset of indicating and cumulative demands.

Through an external input

A self-read is initiated through external input #1. The input is only available when the S4 optional relay board is installed. Using the external input to actuate self-reads may be programmed to occur on either the presence or absence of a signal on external input #1.

Note: Test Mode disables external inputs.

7.17.5 Self Read Displays

When self-read displays are enabled, self-read data will follow the user-programmed display sequence. If the display is currently in the ―normal‖ mode, self-reads are enabled, and there has been an automatically generated self-read, this data will follow the normal display sequence. Self-read data is displayed using the same programmed display sequence that normal real-time data uses. Self-read data will be displayed in chronological order starting from the most recent block. For example, if the time, date, and maximum kilowatts are to be displayed in the normal mode sequence, then when self-reads are displayed, the time, date, and maximum power data recorded in the self-read will be displayed beginning with the most recent self-read data. When the datum in the programmed display sequence does not have a corresponding datum in a self-read, dashes will be displayed on the screen.

When self-read data is being displayed, the display identification value will be modified to indicate that the data is from a self-read block and not real-time data. If the first character of the display ID is blank, the number of the self read block being displayed will be inserted. For example, if the display ID for time is 12 then the current time value will have the display ID 12, the time value of the most recent self-read block will have ID 112, the time value of the second self-read block will have the display tag 212, etc.

49

8. Outputs, Inputs, and Communications The S4 option board has up to four form ―C‖, opto FET, general purpose, output relays and two general purpose inputs. Three different combinations can be ordered and programmed as outlined in the following chart. The AXL does not support options.

Options

One Relay: Programmable for KYZ, EOI, LC, DTA, GyrBox Alert Output, Power Factor Threshold Alert, and Voltage Threshold Alert.

No Input

Two Relays: Each relay programmable for KYZ, EOI, LC, DTA, VTA, GyrBox Alert Output, and Power Factor Threshold Alerts.

One Input: Input programmable for Real Time, Load Profile Channel Input, or self-read activation.

Four Relays: Each relay programmable for KYZ, EOI, LC, DTA, VTA, GyrBox Alert Output, and Power Factor Threshold Alerts.

Two Inputs: Input 1 programmable for Real Time and Load Profile Channel Input.

Input 2 programmable for Load Profile Channel Input.

Table 8.0 Option Board Inputs/Outputs

8.1 Output Cables and Connectors

The S4 meter equipped with options can be provided with an optional output cable which exits through the meter base via a 20 pin connector.

The electronic option board on the S4 meter is a plug-in type in order to facilitate easy addition or removal. For quick reference, each meter has a tag on the option cable showing the option installed on that meter, along with the wire colors, see table below:

Option Connectors

pin #

description

wire color

1

Input 2A

Blue

2

Input 2B

Orange

3

Relay 3 Common

Violet

4

Relay 3 N/0

Yellow/ White

5

Relay 3 N/C

Blue/ White

6

Relay 4 Common

White

7

Relay 4 N/O

White/ Gray

8

Relay 4 N/C

White/ Red

9

Unused

10

Unused

pin #

description

wire color

11

Input 1A

Tan

12

Input 1B

Pink

13

Relay 1 Common

Red

14

Relay 1 N/O

Yellow

15

Relay 1 N/C

Black

16

Relay 2 Common

Brown/ White

17

Relay 2 N/O

Green/White

18

Relay 2 N/C

Orange/White

19

Unused

20

Unused

Table 8.1 Option Connectors and Wire Colors for Output Cables

50

8.2 Inputs 1 and 2

8.2.1 Real-Time Communication Links

The real-time communications link allows the utility to change the active rate in real time. Real-time rates may be achieved in two ways: 1) External Input 1 may be programmed to initiate a real-time rate; or 2) a communication command may be used to initiate a real-time rate. Real time may be used to reduce system peak demand by switching to a premium rate or to encourage more usage by switching to a low-cost rate.

To use real-time communications, install a communications board in the meter. The active rate may be changed at any time by sending the appropriate command. Consult the 1132Prog/1132Com help file for more information about the necessary commands.

Using the real-time input

1) Program the meter so that Input 1 is configured for real-time.

2) Select a rate, A, B, C, D, or E, to use when real-time is active, Demand Meter will not have rate selection.

3) Select whether a high or low signal activates real-time (1132Prog/1132Com for more information).

4) Attach the activating device to Input 1 wires on the option cable. Polarity should match program.

Note: The activating device must be capable of supplying the voltage and current indicated in Section 8.4. To use the low range, resistors R1 and R2 must be removed with a wire cutter. Typically the real time rate used is a different rate from those defined in the TOU schedule.

8.2.2 External Load Profile Inputs

Inputs 1 and 2 may be programmed as load profile inputs. Each input may have its own channel in load profile. In this mode, the meter acts as load profile recorder with two inputs. Other channels may be used for recording any of the meters metrics explained in the load profile section.

51

8.3 Output Relays 1-4

Figure 8.3 provides an illustration of the suggested KYZ Output connection.

RELAY

Figure 8.3 Suggested KYZ Output Connection

8.3.1 KYZ Pulse Outputs

Pulse Initiator Output circuits are provided by the programmable relays. The DGCOM meter uses squared values. Any of these measurement units may be assigned to any of the 4 programmable relays as KYZ outputs:

1). +kWh 6). Leading VAh

2). - kWh 7). VAhrms

3). Lagging VARh 8). V2h or Vh per phase

4). Leading VARh 9). I2h or Ih per phase

5). Lagging VAh 10). I2h or Ih from Neutral Current

8.3.2 KYZ Pulse Constant Ke

Each KYZ output relay is assigned an independent Ke constant that represents the quantity of energy for the output pulse. The meter is programmed with a Ke value in units per pulse depending on the functionality of the relay. The minimum value of Ke is Kh/12, using the meter‘s true Kh. A value of zero disables the KYZ output. Scale factor has no effect on KYZ relays.

If the KYZ metric is volts, the pulse values will be those represented in Table 7.10.5.1. If, however, amps are used then the pulse values will appear as in Table 7.10.5.2.

52

8.3.3 TOU Load Control

TOU Load Control may be assigned to any of the programmable relays. When TOU Load Control is selected, the TOU Load Control output operates at switch points on quarter hours. Load Control is normally based on a TOU schedule and is accomplished by using Schedule in the Normal Mode in a TOU database and also defining it as being scheduled in the rates database. For a Demand meter, it may be selected as always On or Off in a Mode.

8.3.4 End of Interval Output (EOI)

This optional programmable relay switch may be programmed for EOI, in which case it provides a 10 second relay closure at the end of each demand interval.

8.3.5 Demand Threshold Alerts (DTA)

Demand Threshold Alerts are programmable to function as kW, kVAR, or kVA demand and are based on the meter‘s true Kh. Any of the four programmable output relays can be selected to provide a contact closure when the demand exceeds the threshold programmed into the register. The demand threshold at which the DTA output is energized is programmable in the form XXX.XXX. The DTA output is energized immediately when the programmed demand threshold is reached. Once energized, DTA will de-energize at the end of the first complete interval/subinterval in which the demand threshold is not exceeded. If the meter is in test mode the DTA will de-energize at the end of the interval and not at the end of the next. The DTA can be selected to operate only during specified TOU rates or at all times. Demand thresholds have the ability to operate from the selectable metric (KM). The DTA relay can also trigger the meter to enter real time rate. For firmware versions 4.20 and lower the DTA is an instantaneous value and is a direct measurement of voltage and current. Firmware versions 4.22 and greater use a cumulative value for DTA.

Note: The relays can be programmed as either PFTA or DTA for real time activation but cannot be programmed as both PFTA and DTA.

8.3.6 Power Factor Threshold Alerts (PFTA)

The Power Factor Thresholds can be programmed to operate on lagging loads, leading loads, or both and with a value of .001 to 0.999. The relay is activated when the Power Factor threshold is exceeded and is deactivated at the end of the next complete subinterval in which the Power Factor does not exceed the threshold value. The register, through software, allows the PFTA function to cause the programmed real-time rate to go into effect.

8.3.7 Voltage Threshold Alerts (VTA)

Voltage Threshold Alerts operate in much the same way as DTA. The relay activates when the Voltage Threshold is exceeded and is deactivated at the end of the next complete subinterval in which the VTA does not exceed the threshold value. Voltage Thresholds can be selected to operate only during specified TOU rates or at all times.

8.3.8 Diagnostic Alerts

One relay can be programmed for GyrBox Diagnostic Alerts. Whenever any diagnostic check fails, an alert is given. The alert is not cleared until all diagnostics are passed.

53

8.3.9 Operation of Outputs During Test Mode

During test mode, all outputs are available except for load control.

8.4 Electrical Specifications for KYZ Boards (absolute maximums)

Output Relays 1-4 (See Figure 8.3 in Section 8.3 for the suggested KYZ output connection).

60 mA maximum

350 Vdc/240Vac rms maximum

On resistance 50 ohms maximum

Input 1 and Input 2

Input 1 and 2 Standard 5V system*

Voltage 14-24V (DC)

16-26V (AC)

Low: 0-4V (AC/DC)

High: 4-6V (DC)

Low: 0-1V (DC)

Current 10 mA Max. 10mA Max.

*Requires removal of resistors (R1 and R2)

8.5 Optical Port Communications

The S4 meters have an ANSI Type II optical port. The meter may be read by any DGCOM device or ANSI device for the two respective meter types.

8.6 MODEM Communications Board

An optional MODEM communications board provides an alternate communication channel to the meter. Communications boards (MODEM, RS485 or RS-232) are installed parallel to the register board. The 12 pin connector plugs into the same header as the optional relay board. In the case where a relay board is also present, communication boards plug into the 12 pin header on the relay board.

8.6.1 Basic Operation

The basic operation of the MODEM is to allow access to the S4 from a typical telephone connection. Once a telephone connection is established, all functions that are normally available through the optical port are available through the MODEM. In addition, a MODEM password can be programmed which will allow the phone connection to be established only when the caller provides the correct password.

54

8.6.2 Hardware Description

MODEM communication is via an isolated two-wire interface located in the meter‘s base using an RJ-11 jack compatible with standard telephony equipment. This interface uses the same communication protocol as the optical port. Baud rates of 300, 1200, 2400 and 9600 are supported.

8.6.3 Power up Actions

Every time power is supplied to the meter, the MODEM communicates with the S4. This communication occurs approximately six seconds after power-up. At this time the meter is determining the presence of a MODEM, it‘s type and configuration.

The S4 stores the MODEM‘s ID and status for use in future communications. If the S4 has not been programmed with any MODEM configuration program, the MODEM defaults to an answer only mode with an eight-ring answer count.

8.6.4 Operating Modes

There are two operating modes for the MODEM: call answer and call-in. The modem can be programmed to operate in either mode. These operating modes are described below.

Call Answer

Call answer mode governs the conditions under which the MODEM will answer the phone and establish a connection. You can simply program the MODEM to answer after a certain number of rings, or you can program more complex operations such as a TOU type answer schedule (S4 in TOU mode only), defining daily windows during which the phone will be answered. These programming options are detailed in the 1132Prog/1132Com help file. When a call is placed to the MODEM, it will provide its current status and show if any call-ins have occurred since the last power outage.

Call-In

Call-in mode can be triggered by several different types of events. Each event can be programmed independently. The following table contains a brief definition of each call-in event.

Call-In Event Definition

Real Time Entry Call-in on real time mode being activated

Real Time Exit Call-in on real time mode being deactivated

Meter Error Call-in on Error Code 1 and Error Code 2 errors (each error independently programmable)

External Input Call-in on the S4s external input 1 being activated or deactivated

VTA Call-in when a VTA occurs

55

Call-In Event Definition

PFTA Call-in when a PFTA occurs

DTA Call-in when a DTA occurs

Power Restoration Call-in when power is restored

GyrBox D1 Call-in on a D1 error occurring






Additionally the MODEM can be programmed to call-in during certain time windows. This is similar to the way in which the answer window functions during call answer mode. Again this feature is only available for S4s operating in TOU mode. Call-in programming options are detailed in the 1132Prog/1132Com help file.

8.7 RS-232/RS-485 Communications Board

An optional RS-232/RS-485 communications board provides an alternate communications channel to the meter. Communications boards are installed parallel to the register board. The 12 pin connector plugs into the same header as the optional relay board. In the case where a relay board is also present, communications boards plug into the 12 pin header on the relay board.

RS-232/RS-485 communications are transmitted via an isolated three-wire interface located in the meter‘s base using an RJ-11 connector. The three lines (transmit, receive, and ground) each provide 2500 Vrms isolation. This interface uses the same protocol as the optical port. A 9600 baud rate is supported.

56

9. Troubleshooting and Error Codes

9.1 Error Codes

Non-Scrolling errors

Non-scrolling errors are flagged with the number 1 and cause the error code byte to lock at the end of the display sequence. Activating the reed switch will cause auto-scrolling to continue for one more pass in the alternate display mode.

Scrolling errors

The scrolling errors, flagged with the number 2, allow auto-scrolling to continue with the error code byte inserted at the end of the display sequence. With communication add-on boards, the meter has the capability to phone the utility when errors occur.

Error Condition Non-Scrolling Error Display

Scrolling Error Display

Low Battery Voltage ERR 000001 ERR 000002

Unprogrammed Register ERR 000010

Memory Error ERR 000100

Phase Error ERR 000200

Demand Overload ERR 001000 ERR 002000

Stuck Switch ERR 010000 ERR 020000

Unsafe Power Fail ERR 100000

Measurement Diagnostics Failure ERR 200000

Table 9.1 Error Codes

9.1.1 Low Battery Error (ERR 000001 or 000002)

The battery voltage is automatically checked each day at 4 a.m. The error is set when the voltage drops to 2.5 0.2 volts. A check of the battery may be initiated manually also any time

the register goes from Auto-scroll mode to Manual scroll mode (first actuation of scroll switch), each time the register is put into Test mode, and each time a Demand Reset is performed.

Note: A good charge on the supercap does not mask the state of a bad battery.

To clear this error, install a new battery and perform a battery retest as described above.

9.1.2 Unprogrammed Register Error (ERR 000010)

If the meter is unprogrammed, error code 000010 will be displayed.

To clear this error, program the meter.

57

9.1.3 Memory/Load Profile Error (ERR 000100)

A hardware failure in the serial EEPROM or a checksum error in the ROM, SRAM, or EEPROM triggers a memory/load profile error. Internal error flags indicate which of the four components is the source of the error. The following error flags can be seen as a 2-hex digit value in View Data (ex: Memory Error Yes [01]).

Bit Error Description Bit Error Description

0 EEPROM checksum 4 Load profile parity

1 reserved 5 ROM checksum

2 reserved 6 Serial EEPROM

3 reserved 7 SRAM board missing / malfunctioning

To clear the error for bits 0-6, cold start and reprogram the meter. If the error reappears, return the meter for service.

To clear the error for bit 7, make sure the RAM board is seated properly. If you have purposely removed the RAM board, you may get this error because you did not reprogram the meter to exclude load profile. If that is the case, you may need to complete the reprogramming. If, however, you did not remove the RAM board, then the error for bit 7 may indicate that there is a problem with the RAM board. In that case, you should attempt to cold start and reprogram the meter. If the error reappears, return the meter for service.

9.1.4 Demand Overload Error (ERR 001000 or ERR 002000)

At the end of every interval the current demand value is compared against the programmed overload value. If the value is equaled or exceeded, the overload error code (ERR 001000) is latched. Programming the overload value to zero will disable this function.

The overload value is cleared if a cold start or reprogramming is initialized. Also, a demand reset may be programmed to clear the demand overload error. Typically, demand overload is set to 83.3% of the system's capacity.

9.1.5 Stuck Switch Error (ERR 010000 or ERR 020000))

ERR 010000 is displayed when any one of the following situations occur: 1) Reset switch is in active mode for a period of four minutes; 2) Scroll switch is in active mode for a period of four minutes; 3) Test Mode switch is in active mode for a period of 4 minutes after the exiting test mode via the optical command or test mode time out.

This error will be cleared when the switches are returned to normal.

9.1.6 Unsafe Power Fail Error (ERR 100000)

If the S4 register determines that power recovery has occurred without proper power-down mode, it displays error 100000.

To clear the error, cold start the meter.

58

9.1.7 Phase Error (ERR 000200)

The S4 does not have potential indicator lamps but registers the loss of phase voltage by blinking the potential indicator for that phase; see Figure 3.1.1. No displays appears other than the error code displays, which may be seen by pressing the scroll switch. The unknown service type error occurs if the meter has never detected a valid service type.

Phase error displays disappear when voltage is restored. Normal scrolling continues automatically.

The unknown service type error clears when the meter is put in a valid service.

The S4 meter is powered from phase C, so any loss to this phase powers down the whole register and is treated as a normal power failure. Losses of phase A or B will cause an error message to appear. A phase is considered lost at 50% of the nominal voltage. Based on the programmable option of the reader/programmer, the phase error display discontinues auto-scrolling either temporarily or completely. When auto-scrolling is temporarily discontinued, the phase error appears on the display until the scroll switch is pressed. Auto-scrolling then continues for one pass. Any other error codes will appear in their programmed manner with the phase error(s) display returning at the end of this sequence. If auto-scrolling is completely discontinued, the register may only be read electronically.


0 Phase C out 3 Phase A out

1 Phase B out 7 Unknown Service Type

9.1.8 Measurement Diagnostics Failure (ERR 200000)

This error indicates a problem with the ASIC. This is a critical error if the meter is out of calibration.


0 ASIC not initialized 1 DSP initialization error

2 DSP communication error 6 DSP Timeout Error

3 ASIC data overrun 7 Out of Calibration/Critical

9.2 Disabling Display of Error Codes

Each error code may be individually programmed to be displayed or not displayed. All error codes will still be flagged by the register. Reference the 1132Prog/1132Com help file for more details. The reader programmer may clear any error flag, regardless whether or not it is displayable. The meter has a programmable mask to allow the reader/programmer to enable or disable individual error conditions. The reader/programmer may clear any error condition by toggling the appropriate mask bit. If cleared, the register retests for the error.

59

10. Measurement Techniques The following sections briefly describe the methods of measurement for the S4 meter. For a more detailed discussion of measurement techniques used in metering, please refer to the Handbook for Electricity Metering.

10.1 Metric Calculations

The term metric (kM) refers to any electrical units being measured. Typical metrics are watthours, VA hours, kVA, kVAR, volts, and amps, to name a few. Other values such as power factor are based upon these measurements. In the S4 meter there are two fundamental types of measurements - vectoral and rms.

10.1.1 Vectoral Metrics

Arithmetic measurements are generated by basic mathematical functions such as multiplication, division, subtraction, and addition. Watthours are an example of an arithmetic metric. Each voltage sample is multiplied by each current sample and the product is accumulated. When a value representing the K Factor, or Kh/12, is reached, then a pulse is generated. Twelve pulses equal one equivalent disk revolution or Kh of the meter. The accumulated value will typically exceed Kh.

Similarly, VAR measurements are made by integrating the voltage waveform to obtain a 90

phase shift, then each voltage sample is multiplied by the coincident current sample and the product is accumulated to obtain a VARs.

The Scale Factor also affects the Kh in the following manner:

The DSP sends information to the meter‘s processor. The meter‘s processor converts the information into pulse values. Based on the scale factor the pulses are divided down and stored, i.e. Scale Factor = 2 would record half as many pulses as Scale Factor = 1. The pulses (after scaling) are recorded in Load profile, energy registers, and demand registers. The Kh programmed into the meter is adjusted for the scale factor so that the values of energy and demand on the display read accurately.

10.1.2 RMS Metrics

Root-mean-square, or rms metrics, differ significantly from vectoral metrics. The term mean signifies the average or mean value of a series of numbers over time. If the individual numbers of the series are multiplied by themselves, or squared, this creates a series of squared values. By taking the mean of this series, the mean-squared value of the series is obtained. By taking the square root of the mean-squared value, the rms value is obtained. An rms value is the square root of the average of a sum of squared values. The rms value of the voltage is represented by a capital V and the rms of the current is represented by a capital I. V multiplied by I is the metric VA, an rms metric.

In a 4 wire wye system, VArms is calculated by multiplying the rms phase to neutral voltages by the matching rms phase currents, then summing the three products to arrive at the total VA.

60

In a 3 wire delta system, the total VArms is calculated by multiplying two rms line voltages by the matching two rms line currents. These products are then multiplied by a factor of 0.866 and summed to arrive at the total VA.

In a 4 wire delta system, VArms is calculated by multiplying the three rms line to neutral voltages by the corresponding rms line currents. These products are then multiplied by 0.9282 and summed to arrive at the total VA.

10.2 Digital Implementation

For a digital implementation, the voltage and current waveforms must be transformed into a digital format. Once digitized, the values must be used to calculate metrics, and the metrics are then stored and made available for end use. Metrics are either presented on an LCD display or read from memory through a communication port.

10.2.1 Overview of S4 Implementation

Voltage and current transducers provide a representation of the actual voltage and current waveforms as input to a power meter interface ASIC (ASIC). The ASIC contains a digital signal processor (DSP) where energy, power, and other measurements are calculated.

10.2.2 Input Circuitry

The design of the input circuitry allows for the meter to withstand 10KV transient surges without damage. Resistors are used to reduce the line voltage to a level compatible with the solid state circuitry. The scaled potential is input into the ASIC. Similarly, the current is converted for input to the ASIC. The transformer-rated S4 uses current transformer sensors while the self-contained K-base version uses an embedded coil sensor in each phase. Embedded coils provide an output that is proportional to the rate of change of the load current with respect to time, and the external input to the ASIC provides an integration function to restore the current wave form to its original shape. Both types of current sensors provide 10 kV of isolation.

Voltage and current inputs from each phase are sampled by two (Delta Sigma)

converters. Once sampled, a single 20-bit analog to digital converter (ADC) digitizes the sample and transmits the data to a digital signal processor.

10.2.3 Sampling Rate

Voltage and current pairs are sampled by the converters at a rate of 3.33 Mhz. These

samples are filtered digitally to provide a 20 bit value representing the input at 3.34 kHz. This makes it possible to discern frequency up to the 26th harmonic of 60 Hz. Note: Frequency is only calculated when potential is applied on all 3 phases.

10.2.4 Register Section

The DSP in the measurement ASIC calculates metric values. A communications serial bus is used to transfer metric data from the ASIC to the micro-controller. These are both on the primary printed wiring board. All metric data is calculated by the DSP except for VA. VA is calculated by the micro-controller.

61

10.3 Negative Energy Metric

The RXS4 register may be programmed to treat negative energy in two different ways, security (add) mode and detent (ignore) mode. In all instances of negative energy measurement, the digital power indicator will operate from right-to-left and the negative energy accumulator increments.

10.3.1 Security (Add) Mode

In security (add) mode, negative energy is treated as if it were positive energy. kWh is accumulated positively in the total kWh register. Demand functions operate in their normal manner. All optional outputs function normally. Negative energy is also accumulated in the negative energy register.

10.3.2 Detent (Ignore) Mode

Negative energy is accumulated in the negative energy register and ignored in the normal (positive) energy register used for billing purposes. In detent mode, all negative watt and watthour measurements are ignored for billing purposes.

10.3.3 Net Mode

In ANSI protocol meters (firmware versions 6.xx) Net mode has been added. In Net mode negative watthour measurements are accumulated and subtracted from the normal (positive) energy register for billing purposes.

10.3.3 Leading kVARh Accumulator

The S4 includes a VARh accumulator for leading power factors only. When combined with a negative kWh in detent mode, a kMh set up for VAR (ignore leading), and a total Wh, this feature gives the user the ability to measure energy on all four axes of the power quadrant (see Section 10.4).

10.3.4 VArms, kVARtd, kVAtd measurements

kVArms is a measured quantity and, therefore, includes both lead and lag components of the load. kVAR demand is always calculated as if ―ignore‖ were selected for leading conditions. kVAR energy can either add, subtract, or ignore leading kVARh from lagging kVARh. kVAtd, for both demand and energy, may either add or ignore leading kVAtd.

10.4 50 Hz Operation

The S4 meter is normally calibrated at 60 Hz, but will operate at either 50 or 60 Hz. Upon power-up, the meter checks the frequency, and operates on the frequency it registers. In addition, you may order a meter to be specifically calibrated at 50 Hz. Consult the factory for details.

62

10.5 Power Quadrant Indicators

On the LCD, a numbered four quadrant ―pie‖ indicates the combined load on the meter. The chart below outlines the load when that quadrant is highlighted.

Quadrant I Positive watts (delivered) VAR (delivered) / (lagging power factor)

Quadrant II Negative watts (received) VAR (delivered) / (leading power factor)

Quadrant III Negative watts (received) VAR (received) / (lagging power factor)

Quadrant IV Positive watts (delivered) VAR (received) / (leading power factor)

10.6 Overview of the S4 Measuring Element

The S4 utilizes a digital sampling technique to measure voltage and current in a customer load. The S4 calculates active, reactive, and apparent power in quadrants one and four. Apparent power is calculated as the product of the square-root of the mean-square value of the current (Irms) and voltage (Vrms). Calculations include harmonics of the fundamental, up to and including the 23rd harmonic.

63

10.6.1 S4 Measurement Metrics—Second (kM) and Third Metric (kM3)

Functionally, the meter always operates on active energy (kWh & kW) and two selectable additional metrics. The additional metrics apply to both energy and demand functions. Additional metrics available in the register (shown here in energy units) are as follows:

+VARh (phase shift) Ignoring, Adding or Netting Leading VARh

VAh (rms)

+VAh (time delay Ignoring or Adding Leading VAh

In addition the meter always stores leading VARh and negative Wh

Active energy and the second metric (kM) are supported for TOU functionality, while the third metric (kM3) has no TOU registers.

10.6.2 Neutral Current Calculations

Measurement of the neutral current of an S4 is a calculated quantity. Note that when certain meter forms such as the Form 12 and Form 5 are used in a "network" installation, the information necessary to determine neutral current is not available. This is because typical network application may have several meters supplying kWh information from a single three phase, four wire "Y" distribution transformer. There are three phase currents, but only two are metered by any one single meter. Each meter shares the common neutral.

To calculate true neutral current, all phase currents must be known by a single meter. As a result, neutral current cannot be determined by any of the meters and should be ignored in these applications.

10.6.3 Register Metric-Hour Constant (Kh)

Registration of energy is based upon the register constant Kh. The Kh value is normalized to 120 volts. Since the S4 meter operates from 120-480 volts, the registration of energy at 480 volts is at a rate four times greater than at 120 volts for the same load current. Thus, one Kh value suffices for all applicable voltages. The meter is capable of registering energy at this rate, but some external devices, such as pulse recorders, may not be. See Section 11.2 for a discussion of output pulse rates for calibration verification.

Each pulse represents one Kh/12 amount of energy. The pulse count is stored in the meter's memory and is read by a reader. To determine the amount of energy recorded by the meter, the following formula should be used:

Energy = [pulse count] x Kh/12

Where: Energy = watt-hours, VA hours or VAR hours.

Pulse count = pulses

Kh = watt-hours or VAR hours per disk revolution

64

Kh is used to calculate the proper kWh and kW values for display. The S4 uses one Kh value per meter form. For each form, the Kh value is based on 120V. As the voltage changes from service to service, the Kh remains the same. A Kh value can be programmed to a value other than the meters true Kh. If this is done, the energy and demand registers will be affected by the new Kh, however, the KYZ and DTA output relays will continue to use the meter‘s true Kh.

For S base, A base and SE base:

Form Kh

9/8 1.8

12 14.4

16/15/14 21.6

25 14.4

29 1.8

36 (6) 1.8

45 (5) 1.2

2 7.2

3 .3 or .6

For K base:

Form Kh

12 28.8

16/15/14 43.2

27 28.8

10.6.4 Transformer Factor (TF)

A transformer factor can be programmable as a 6-digit number available for display only or as a multiplier to achieve direct primary readings for display.

Transformer factor = CT ratio x the PT ratio

10.7 Power Factor

True power factor is calculated as the ratio of active power to apparent power.

Note: The power factor calculations described below are based on true power factor, power factor is calculated using the following two methods:

rmsPowerFactorW

VA

where V*A is based on rms quantities and using the kVA rms calculation, or:

ReactivePowerFactorW

W VAR2 2using the kVA td power factor calculation

65

10.7.1 Available Power Factor Measurements

The following power factor measurements are calculated, stored, and available for display:

Instantaneous power factor

Previous interval power factor

Average power factor since last reset

Smallest power factor since last reset

Power factor for each maximum demand, including kW, kM, or kM3

10.8 Effects of Harmonic Distortion

The S4 responds within the limits below when a voltage composite wave form and a current composite wave form are simultaneously applied. With this test, the voltage composite wave form consists of the fundamental plus one harmonic component at 10% of the fundamental amplitude. The current composite wave form consists of the fundamental plus one harmonic component at 30% of the fundamental amplitude. The harmonic components are applied one at a time.

Harmonic Number Error Limits (%)

3 0.7

5 1.0

7 1.4

9 1.7

11 2.1

13 2.4

15 2.8

17 3.1

19 3.5

21 3.9

23 4.2

The following composite waveforms are applied to the voltage and current simultaneously, where IP = Peak Current. VARms and Watt accuracy tests are performed at full load and light load.

I = Ip[sin( t) + 0.3sin(n t)]

I = Ip[sin( t) - 0.3sin(n t)]

I = Ip[sin( t) + 0.3sin[n t + (p/2)]]

I = Ip[sin( t) + 0.3sin[n t - ( /2)]

n = Odd Harmonic Number from 3 to 23

V = Vp[sin( t) + 0.1sin(n t)]

66

11. Calibration Verification and Testing

11.1 S4 Factory Calibration

Calibration of voltages, currents and phase angles per element is accomplished through calibration constants stored in non-volatile memory. These constants cannot be changed except by recalibration at the factory

11.2 How to Verify the S4 Calibration

11.2.1 Verification of Watt Calibration

S4 watt calibration may be verified using standard procedures. The watt calibration LED is the left LED located inside the Type II optical port on the face of the polycarbonate cover. The infra-red output pulses from the LED can be changed through programming with the 1132Prog/1132Com software packages. The optical pulse rate can be selected to be either medium (one pulse per equivalent revolution), fast (12 pulses per equivalent revolution), or slow (1 pulse for every 4 equivalent revolutions).

11.2.2 Calibration Pulse Displays

Three calibration pulse displays, used in the test mode sequence, give calibration pulses other than watts. Whenever the meter is in test mode and scrolled to one of these displays (one for VAR, one for VArms, one for VAtd), the meter will start pulsing in these metrics. At all other times the meter will give watt pulses. Each display will show ―CAL‖ in the seven segment portion of the LCD and include the appropriate units on the right side of the LCD.

11.2.3 Test Times

The minimum test times required to obtain accurate verification for S4 calibration are given below. Testing at power factors other than those specified below will require longer test times.

Quantity Present Minimum Test Time

Watthour TA 21.6 seconds @ unity PF

VA phase shift TA 90 seconds

VAR TA 90 seconds

VArms TA 90 seconds

When testing, the test board should have a 6 second settling time programmed. This will allow 6 seconds for the calibration pulse to stabilize when the current changes. Allow 15 seconds if the meter has a modem.

67

11.2.4 Field Testing

To test the meter in the field using test mode, complete the following procedure:

1) Remove the cover.

2) Flip the test mode switch. The LCD will indicate the meter is in test mode.

3) Press the scroll button to scroll through the displays.

4) Exit test mode by returning the test mode switch to its original position.

11.2.5 Demand Measurement Verification

In order to test the demand measurement of an S4 meter, complete the following procedure:

1) Connect the reference standard to the meter.

2) Select the voltage test to match the application.

3) Turn on the pulse counting device and make sure it is set to 0.

4) Flip the test mode switch.

5) Press the Demand Reset button.

6) Turn on the current to the meter and the standard at the same time.

7) After the End of Interval flag is displayed; turn off the current to the meter and the standard, again at the same time.

8) Record the pulse counter total and compare it with the total on the S4 display.

A.1

Appendix A: Technical Specifications

General Conditions

Nameplate Voltage Vn = 120- 480 VAC

Rated Frequency Fn = 50 or 60 Hz ± 5%

Power Factor PF = 1.0

Ambient Temperature TA = 23° C ±5° C

Temperature (inside cover) -40° C to + 85° C

Operating -40° F to +185° F

Humidity (non-condensing) Relative Humidity <=95% Rh

Input Specifications

Voltage Withstand:

Effect of High Voltage Line Surges (ANSI/IEEE C62.41)

6KV (1.2/50µs-8/20µs combination wave and 100kHz ring wave at .05µs-100kHz)

Surge Withstand Capability (ANSI C37.90A)

Oscillatory 3 kV (1 mHz; 100 Hz, 10 seconds)

Fast Transient 5Kv (50 pulses/sec, 20 seconds)

Temporary Overvoltage Withstand (0.5 seconds) 150% of Vn

Continuous Overvoltage Withstand ( 5 hours) 130% of Vn

A.2

Internal Meter Losses (Burden), exceeds ANSI Standards Below:

Class 20, 200, 320 Phase A & B Phase C

Potential 120V 20 VA 20 VA

240V 20 VA 20 VA

480V 20 VA 20 VA

Current 20 Amps 0.5 VA 0.5 VA

200 Amps 1.0 VA 1.0 VA

320 Amps 1.0 VA 1.0 VA

Length of 100% Power Loss Resulting in No Power Down of the Register:

Power loss duration @ Vn 100 milliseconds Minimum

Current System:

Test Amps Starting Load Continuous Max (5 hours)

Temporary Max (6 line cycles)

Class 20 2.5 Amps 0.005 Amps 30 Amps 400 Amps

Class 120 30 Amps 0.050 Amps

Class 200 30 Amps 0.050 Amps 250 Amps 7000 Amps



No Load (Creep)

With potential applied over the entire line voltage range of the meter and no current flowing in the current circuit, there shall be no pulse accumulation in the register. The test for no pulse accumulation shall be conducted over a period of 24 hours.

A.3

Applicable Standards

ANSI C12.1 - 2001 for electricity metering

ANSI C12.10 - 1997 for watthour meters

ANSI C12.18 – 1996 Protocol Specification for ANSI Type 2 Optical Port

ANSI C12.19 – 1997 Protocol Specification for Utility Industry End Device Tables (ANSI Protocol S4e only)

ANSI C12.20 – 2002 for Electricity Meters – 0.2 and 0.5 Accuracy Classes

ANSI C12.21 – 1999 Protocol Specification for Telephone Modem Communication

CAN3-C17-M84 Canadian specifications for approval of type of electricity meters

CAN3-Z234.4-79 Canadian specifications for all-numeric dates and times

IEC 687 - 1992 (Electrical Specifications)

FCC Class B Emissions

Landis+Gyr Engineering Specification 69343

A.4

Weights and Dimensions

Form Net lbs.

Single Pack Weight

Single Pack Dimensions

Four-Pack Weight

Four-Pack Dimensions

45S (5S) 4 6 lbs 9‖ x 11‖ x 9‖ 19 lbs 15½‖ x 10‖ x 15½‖

36S (6S) 5 6 lbs 9‖ x 11‖ x 9‖ 19 lbs 15½‖ x 10‖ x 15½‖

9S/8S 5 6 lbs 9‖ x 11‖ x 9‖ 19 lbs 15½‖ x 10‖ x 15½‖

12S(E) 4 6 lbs 9‖ x 11‖ x 9‖ 19 lbs 15½‖ x 10‖ x 15½‖

16S(E) 5 6 lbs 9‖ x 11‖ x 9‖ 19 lbs 15½‖ x 10‖ x 15½‖

45A (5A) 7 9 lbs 10‖ x 14‖ x 15½‖

36A (6A) 7 9 lbs 10‖ x 14‖ x 15½‖

10A/8A 7 9 lbs 10‖ x 14‖ x 15½‖

12K 7 10 lbs 10½‖ x 15‖ x 12‖

16/15/14K 8 12 lbs 10½‖ x 15‖ x 12‖

27K 8 12 lbs 10½‖ x 15‖ x 12‖

S4 Meter Component Description

P.B.T. Baseplate:

The S4 baseplate is made of Poly Butyelene Terephathalate or P.B.T. It contains 22.5% glass and 22.5% mineral in an injection molded polyester material. It is rated at 17 to 25 KPSI compared to commonly used Phenolic that has a KPSI rating of 3 1/2 to 4 KPSI. It carries a UL-764 high voltage arc track rating near zero.

Meter Frame:

The injection molded polycarbonate frame is designed with unique "snap-in" features that allow quick and easy assembly or disassembly of major meter components. Connector is made with a "gas-tight" connection to insure electrical connection over time.

Cover:

The cover is made of high strength polycarbonate that will not break even under extreme physical abuse.

A.5

FCC Requirements

1. This equipment complies with Part 68 of the Federal Communication Commission (FCC) Rules and Regulations. These rules permit this device to be directly connected to the telephone network. Standardized jacks are used for these connections. This equipment should not be used on party lines or coin lines.

2. If the Type S4 Electronic Watthour Meter is malfunctioning it may cause harm to the telephone network; the telephone company will notify you in advance that temporary discontinuance of service may be required. If advance notice is not practical, the telephone company will notify you of the discontinuance as soon as possible. You will be advised of your right to file a complaint with the FCC if you believe it is necessary.

3. The telephone company may make changes in it‘s technical operations and procedures; if such changes affect the compatibility or use of this device, the telephone company is required to give adequate notice of the changes. You will be advised of your right to file a complaint with the FCC if you believe it is necessary.

4. If the telephone company requests information on what equipment is connected to their lines, inform them of:

a. The telephone number this unit is connected to

b. Ringer Equivalence Number (REN) for this equipment

c. The USOC jack required

d. The FCC Registration Number

The label on the left side of the meter contains the FCC Registration Number and the Ringer Equivalence Number (REN) for this equipment.

The REN is useful to determine the quantity of devices that may be connected to the telephone line. Excessive RENs on the telephone line may result in the devices not ringing in response to an incoming call. In most, but not all areas, the sum of the RENs should not exceed five (5.0). To be certain of the number of devices that may be connected to the line, as determined by the total RENs, contact the telephone company to determine the maximum REN for the calling area.

This device complies with part 15 of the FCC rules. Operation is subject to the following two conditions: (1) This device may not cause harmful interference, and (2) this device must accept any interference received, including interference that may cause undesired operation.

A.6

In the event of equipment malfunction, repairs should be performed by our Company or an authorized agent. It is the responsibility of users requiring service to report the need for service to our Company or to one of our authorized agents.

If you experience trouble with the Landis+Gyr S4 or S4e Electricity Meters please contact:

Landis+Gyr Inc

2800 Duncan Road

Lafayette, IN, 47904 USA

Phone 800-777-2774

Attn: Product Service Center

for repair and/or warranty information.

Changes of modifications not expressly approved by Landis+Gyr Inc could void your authority to operate the equipment.

B.1

Appendix B: Register Displays

Each display includes a two digit identification number. The identification number can be any number from 0 through 999 or can be a three character alphanumeric code. The identifiers are merely labels; numbers may be repeated and may be in any order.

Except for countdown timers, present demand, instantaneous measurements, and Test Mode displays, display values will not be updated as they are shown, even if the value is changing internally in the meter. To display an updated value, it will be necessary to scroll through all the display items until the value desired appears again.

Displays are shown both in order by display code and by description. The tables on pages B.3-9 list the following information for each display:

Display Name.

Format of the display on the register LCD. An explanation of the formats appears on page B.2.

Whether the display is valid when the register is in demand-only mode ("X" if it is; blank if the display requires TOU programming).

Whether the display is valid for AX registers (―X‖ if it is; blank if the display requires RX register).

Description of the display.

Where "Rate A" displays are indicated as applicable for demand-only devices, Real Time mode is indicated. For example, on a AXS4(Dmd), the "Rate A Total kWh" display indicates Real Time Total kWh. Displays for Previous Season data are abbreviated with "PS". Displays listed as KM refer to the selectable metric while KM3 refers to the third metric, see Appendix E for further definitions.

B.2

Display Formats

All Segment All segments of every character shown on display to verify that display is fully functional.

Alpha-4 Format is four characters. If numeric, the digit is shown. If it is alphabetic and greater than F, a dash is displayed.

Alpha-6 Format is six characters. If numeric, the digit is shown. If it is alphabetic and greater than F, a dash is displayed.

Alpha-9 Format is nine characters. If numeric, the digit is shown. If it is alphabetic and greater than F, a dash is displayed.

Cumulative Display is formatted for demand per LCD Display Configuration Variable command (67h Prgm). This command also dictates if cumulative or continuous cumulative demand is displayed. DX firmware versions less than 2.00 use the same format for normal and cumulative demand. Starting with DX firmware 2.00 and all early versions of RX, cumulative demand has one additional digit to the left of the decimal point. Starting with DX firmware version 2.04 and RX firmware version 2.11, the cumulative demand display format is independently selectable.

Date Display is formatted for dates per the LCD Display Configuration Variable command (67h Prgm).

Demand Display is formatted for demand per the LCD Display Configuration Variable command (67h Prgm). Leading zeros are not suppressed.

Energy Display is formatted for energy per the LCD kWh Display Digits command (30h Prgm)

Float Format is six digit floating point. The decimal location is dynamic (for example, based on the decimal location specified in Ke Values command, 78h Prgm).

Fixed-1 Format is 9.

Fixed-2 Format is 99, with leading zeros suppressed.

Fixed-2.1 Format is 99.9, with leading zeros suppressed.





B.3


Fixed-6 Format is 999999.

Ones-6 Display is one or zero in each of the six large digits. If used as an error display, ID is always ERR.

Pulse Used for S4 test mode calibration displays. The six large digits always show PULSE, and the metric indicator corresponding to the display (e.g. VA rms) will be used. The calibration LED pulses according to this metric.

SDH Format is S9.d9.t9 for season, day of week and type of day.

Time-HM Format is HHMM.

Time-HMS Format is HH.MM.SS.

Time-M Format is MMMMMM, with leading zeros suppressed.

Time-MS Format is MMSS.

Twos-6 Display is two or zero in each of the six large digits and ID is always ERR.

B.4

Register Displays, listed alphabetically

Display Name Format Dmd AX Description

AS LEFT 3 EL FL Fixed-3.3 X X As Left Three Element Full Load

AS LEFT 3 EL LL Fixed-3.3 X X As Left Three Element Light Load

AS LEFT 3 EL PF Fixed-3.3 X X As Left Three Element Power Factor

AS LEFT CE EL FL Fixed-3.3 X X As Left Center Element Full Load

AS LEFT CE EL PF Fixed-3.3 X X As Left Center Element Power Factor

AS LEFT LT EL FL Fixed-3.3 X X As Left Left Element Full Load

AS LEFT LT EL PF Fixed-3.3 X X As Left Left Element Power Factor

AS LEFT RT EL FL Fixed-3.3 X X As Left Right Element Full Load

AS LEFT RT EL PF Fixed-3.3 X X As Left Right Element Power Factor

AVERAGE PF Fixed-1.3 X Average PF Since Last Reset

BLANK Blank X X Blank Display

CAL VOLTAGE Fixed-3.3 X X Calibration Voltage

CUMULATIVE KM Cumulative X Cumulative kM

CUMULATIVE KW Cumulative X X Cumulative kW

CURRENT DATE Date X Date

CURRENT TIME Time-HM X Time

CURRENT TIME/SECS Time-HMS X Time with Seconds

DATE LP LAST READ Date X Date Load Profile Last Read

DATE PROGRAMMED Date X Date Last Programmed

DAYS SINCE RESET Fixed-3 X X Days Since Last Reset

DEMAND INT LENGTH Fixed-2 X X Interval Length in Minutes

DEMAND OVERLOAD Fixed-3.3 X X Demand Overload

DEVICE ID #1 Alpha-9 X X Device ID #1

B.5


DEVICE ID #2 Alpha-9 X X Device ID #2

DIAG COUNTER 1 Fixed-5 X X Diagnostic Counter 1







DTA 1 VALUE Fixed-3.3 X X Demand Threshold Alert (DTA) 1




ERROR CODE 1 Ones-6 X X Error Code 1

ERROR CODE 2 Twos-6 X X Error Code 2

EXTRA REGISTER 1 Alpha-4 X X Extra Register 1

EXTRA REGISTER 2 Alpha-6 X X Extra Register 2

FIRMWARE VERSION Fixed-2.2 X X Firmware Version

FORM Fixed-1 X X Form

HARDWARE VERSION Fixed-2.2 X X DSP Firmware Version Number

I ANGLE PHASE A Fixed-3.1 X X Current Angle, Phase A

I ANGLE PHASE B Fixed-3.1 X X Current Angle, Phase B

I ANGLE PHASE C Fixed-3.1 X X Current Angle, Phase C

INSTANT IRMS A Fixed-5.1 X X Instantaneous Irms, Phase A

B.6


INSTANT IRMS B Fixed-5.1 X X Instantaneous Irms, Phase B

INSTANT IRMS C Fixed-5.1 X X Instantaneous Irms, Phase C

INSTANT KVA LAG Fixed-5.1 X Instantaneous kVA td

INSTANT KVA RMS Fixed-5.1 X Instantaneous kVA rms

INSTANT KVAR LAG Fixed-5.1 X Instantaneous kVAR td

INSTANT KW Fixed-5.1 X Instantaneous kW

INSTANT NEUTRAL I Fixed-5.1 X X Instantaneous Neutral Current

INSTANT PF Fixed-1.3 X Instantaneous Power Factor

INSTANT VRMS A Fixed-5.1 X X Instantaneous Vrms, Phase A

INSTANT VRMS B Fixed-5.1 X X Instantaneous Vrms, Phase B

INSTANT VRMS C Fixed-5.1 X X Instantaneous Vrms, Phase C

K FACTOR Fixed-3.3 X X K Factor

KE 1 Float X X Ke 1

KE 2 Float X X Ke 2

KE 3 Float X X Ke 3

KE 4 Float X X Ke 4

KH Fixed-3.3 X X Kh

LAST RESET DATE Date X Date of Last Reset

LAST RESET KMH Energy X Total kMh at Last Reset

LAST RESET KWH Energy X X Total kWh at Last Reset

LAST RESET MAX KM Demand X Maximum kM at Last Reset

LAST RESET MAX KW Energy X X Maximum kW at Last Reset

LAST RESET TIME Time-HM X Time of Last Reset

B.7


LEADING KVARH Energy X Leading kVARh

LINE FREQUENCY Fixed-2.1 X X Line Frequency

LP INTERVAL LEN Fixed-2 X Load Profile Interval Length

MAX COIN DMD Demand X Maximum Coincident Demand (kunits)

MAX COIN KM3 Demand X Max Coincident kM3

MAX COIN M3 Demand X Max Coincident M3

MAX COIN UNITS Demand X Maximum Coincident Demand (units)

MAX KM Demand X Maximum kM

MAX KM #2 Demand Maximum Demand #2 (Non-Billing Metric)

MAX KM #2 DATE Date Date of Maximum Demand #2 (Non-Billing Metric)

MAX KM #2 TIME Time-HM Time of Maximum Demand #2 (Non-Billing Metric)










MAX KM DATE Date X Date of Maximum kM

MAX KM TIME Time-HM X Time of Maximum kM

MAX KM3 Demand X Maximum kM3 Demand

B.8


MAX KM3 DATE Date Maximum kM3 Date

MAX KM3 TIME Time-HM Maximum kM3 Time

MAX KW Demand X X Maximum kW

MAX KW #2 Demand X Maximum Demand #2

MAX KW #2 DATE Date X Date of Maximum Demand #2

MAX KW #2 TIME Time-HM X Time of Maximum Demand #2










MAX KW DATE Date X Date of Maximum kW

MAX KW TIME Time-HM X Time of Maximum kW

MAX M3 Demand X Maximum M3

MAX METRIC Demand X Maximum Metric

MAX WATTS Demand X X Maximum Watts

MINIMUM PF Fixed-1.3 X Smallest PF Since Last Reset (Farthest from Unity)

MINIMUM PF KW Demand X kW at Smallest Power Factor

MP 1 Fixed-3.3 X X Mp 1

B.9





NEG KWH PULSES Fixed-6 X X Negative kWh Pulses

NEGATIVE KWH Energy X X Negative kWh

NUM DEMAND RESETS Fixed-3 X X Number of Demand Resets

NUM DEMAND SUBINTS Fixed-2 X X Number of Subintervals per Interval

NUM POWER FAILS Fixed-3 X X Number of Power Failures

NUM TM PROGRAMMED Fixed-3 X X Number of Times Programmed

PF AT MAX KM Fixed-1.3 X Power Factor at Maximum kM

PF AT MAX KM3 Fixed-1.3 X Power Factor at Maximum kM3

PF AT MAX KW Fixed-1.3 X Power Factor at Maximum kW

PODT TRIGGER TIME Time-MS X X Power On Delay Time (PODT) Trigger

POWER DELAY TIME Fixed-3 X X Power On Delay Time (PODT)

PREMIUM RATE Fixed-1 X Rate Used for Real Time

PRESENT KM Demand X Present kM

PRESENT KM3 Demand X Present kM3

PRESENT KW Demand X X Present (kW)

PRESENT M3 Demand X Present M3

PRESENT METRIC Demand X Present M

PRESENT WATTS Demand X X Present Watts

PREVIOUS INT KM Demand X Previous Interval kM

PREVIOUS INT KM3 Demand X Previous Interval kM3

B.10


PREVIOUS INT KW Demand X X Previous Interval kW

PREVIOUS INT M Demand X Previous Interval M

PREVIOUS INT M3 Demand X Previous Interval M3

PREVIOUS INT PF Fixed-1.3 X Previous Interval Power Factor

PREVIOUS INT WATTS Demand X X Previous Interval Watts

PROG OUTPUT 1 & 2 Ones-6 X X Programmable Output Setup 1 & 2

PROG OUTPUT 3 & 4 Ones-6 X X Programmable Output Setup 3 & 4

PROGRAM ID Fixed-4 X X Program ID

PROGRAMMER ID Fixed-4 X X Version Number of Last Programmer

PS A COIN DEMAND Demand PS Rate A Maximum Coincident Dmd

PS A CUM KM Cumulative PS Rate A Cumulative kM

PS A CUM KW Cumulative X PS Rate A Cumulative kW

PS A KMH Energy PS Rate A Total kMh

PS A KWH Energy X PS Rate A Total kWh

PS A MAX KM Demand PS Rate A Maximum kM

PS A MAX KM DATE Date PS Rate A Date of Max. kM

PS A MAX KM TIME Time-HM PS Rate A Time of Max. kM

PS A MAX KW Demand X PS Rate A Maximum kW

PS A MAX KW DATE Date X PS Rate A Date of Max. kW

PS A MAX KW TIME Time-HM X PS Rate A Time of Max. kW

PS A PF AT MAX Fixed-1.3 PS Rate A Power Factor at Max Dmd

PS B COIN DEMAND Demand PS Rate B Maximum Coincident Dmd

PS B CUM KM Cumulative PS Rate B Cumulative kM

B.11


PS B CUM KW Cumulative X PS Rate B Cumulative kW

PS B KMH Energy PS Rate B Total kMh

PS B KWH Energy X PS Rate B Total kWh

PS B MAX KM Demand PS Rate B Maximum kM

PS B MAX KM DATE Date PS Rate B Date of Max. kM

PS B MAX KM TIME Time-HM PS Rate B Time of Max. kM

PS B MAX KW Demand X PS Rate B Maximum kW

PS B MAX KW DATE Date X PS Rate B Date of Max. kW

PS B MAX KW TIME Time-HM X PS Rate B Time of Max. kW

PS B PF AT MAX Fixed-1.3 PS Rate B Power Factor at Max Dmd

PS C COIN DEMAND Demand PS Rate C Maximum Coincident Dmd

PS C CUM KM Cumulative PS Rate C Cumulative kM

PS C CUM KW Cumulative X PS Rate C Cumulative kW

PS C KMH Energy PS Rate C Total kMh

PS C KWH Energy X PS Rate C Total kWh

PS C MAX KM Demand PS Rate C Maximum kM

PS C MAX KM DATE Date PS Rate C Date of Max. kM

PS C MAX KM TIME Time-HM PS Rate C Time of Max. kM

PS C MAX KW Demand X PS Rate C Maximum kW

PS C MAX KW DATE Date X PS Rate C Date of Max. kW

PS C MAX KW TIME Time-HM X PS Rate C Time of Max. kW

PS C PF AT MAX Fixed-1.3 PS Rate C Power Factor at Max Dmd

PS CUMULATIVE KM Cumulative PS Cumulative kM

B.12


PS CUMULATIVE KW Cumulative X PS Cumulative kW

PS D COIN DEMAND Demand PS Rate D Maximum Coincident Dmd

PS D CUM KM Cumulative PS Rate D Cumulative kM

PS D CUM KW Cumulative X PS Rate D Cumulative kW

PS D KMH Energy PS Rate D Total kMh

PS D KWH Energy X PS Rate D Total kWh

PS D MAX KM Demand PS Rate D Maximum kM

PS D MAX KM DATE Date PS Rate D Date of Max. kM

PS D MAX KM TIME Time-HM PS Rate D Time of Max. kM

PS D MAX KW Demand X PS Rate D Maximum kW

PS D MAX KW DATE Date X PS Rate D Date of Max. kW

PS D MAX KW TIME Time-HM X PS Rate D Time of Max. kW

PS D PF AT MAX Fixed-1.3 PS Rate D Power Factor at Max Dmd

PS E COIN DEMAND Demand PS Rate E Maximum Coincident Dmd

PS E CUM KM Cumulative PS Rate E Cumulative kM

PS E CUM KW Cumulative X PS Rate E Cumulative kW

PS E KMH Energy PS Rate E Total kMh

PS E KWH Energy X PS Rate E Total kWh

PS E MAX KM Demand PS Rate E Maximum kM

PS E MAX KM DATE Date PS Rate E Date of Max. kM

PS E MAX KM TIME Time-HM PS Rate E Time of Max. kM

PS E MAX KW Demand X PS Rate E Maximum kW

PS E MAX KW DATE Date X PS Rate E Date of Max. kW

B.13


PS E MAX KW TIME Time-HM X PS Rate E Time of Max. kW

PS E PF AT MAX Fixed-1.3 PS Rate E Power Factor at Max Dmd

PS LEADING KVARH Energy PS Leading kVARh

PS MAX KM Demand PS Maximum kM

PS MAX KM DATE Date PS Date of Maximum kM

PS MAX KM TIME Time-HM PS Time of Maximum kM

PS MAX KW Demand X PS Maximum kW

PS MAX KW DATE Date X PS Date of Maximum Demand

PS MAX KW TIME Time-HM X PS Time of Maximum Demand

PS NEGATIVE KWH Energy X PS Negative kWh

PS TOTAL KMH Energy PS Total kMh

PS TOTAL KWH Energy X PS Total kWh

PULSE VA RMS Pulse X Test Mode VA rms pulse

PULSE VA TD Pulse X Test Mode VA td pulse

PULSE VAR TD Pulse X Test Mode VAR td pulse

PULSES CUR SUB KM Fixed-5 X Metric Pulses in Current Subinterval

PULSES CUR SUB KM3 Fixed-6 X kM3h Pulses in Current Subinterval

PULSES CUR SUB KW Fixed-5 X X kWh Pulses in Current Subinterval

RATE A COIN DEMAND Demand X Rate A Maximum Coincident Demand

RATE A CUM KM Cumulative X Rate A Cumulative kM

RATE A CUM KW Cumulative X X Rate A Cumulative kW

RATE A KMH Energy X Rate A Total kMh

RATE A KWH Energy X X Rate A Total kWh

B.14


RATE A MAX KM Demand X Rate A Maximum kM

RATE A MAX KM DATE Date Rate A Date of Maximum kM

RATE A MAX KM TIME Time-HM Rate A Time of Maximum kM

RATE A MAX KW Demand X X Rate A Maximum kW

RATE A MAX KW DATE Date X Rate A Date of Maximum kW

RATE A MAX KW TIME Time-HM X Rate A Time of Maximum kW

RATE A PF AT MAX Fixed-1.3 X Rate A Power Factor at Maximum Dmd

RATE B COIN DEMAND Demand Rate B Maximum Coincident Demand

RATE B CUM KM Cumulative Rate B Cumulative kM

RATE B CUM KW Cumulative X Rate B Cumulative kW

RATE B KMH Energy Rate B Total kMh

RATE B KWH Energy X Rate B Total kWh

RATE B MAX KM Demand Rate B Maximum kM

RATE B MAX KM DATE Date Rate B Date of Maximum kM

RATE B MAX KM TIME Time-HM Rate B Time of Maximum kM

RATE B MAX KW Demand X Rate B Maximum kW

RATE B MAX KW DATE Date X Rate B Date of Maximum kW

RATE B MAX KW TIME Time-HM X Rate B Time of Maximum kW

RATE B PF AT MAX Fixed-1.3 Rate B Power Factor at Maximum Dmd

RATE C COIN DEMAND Demand Rate C Maximum Coincident Demand

RATE C CUM KM Cumulative Rate C Cumulative kM

RATE C CUM KW Cumulative X Rate C Cumulative kW

RATE C KMH Energy Rate C Total kMh

B.15


RATE C KWH Energy X Rate C Total kWh

RATE C MAX KM Demand Rate C Maximum kM

RATE C MAX KM DATE Date Rate C Date of Maximum kM

RATE C MAX KM TIME Time-HM Rate C Time of Maximum kM

RATE C MAX KW Demand X Rate C Maximum kW

RATE C MAX KW DATE Date X Rate C Date of Maximum kW

RATE C MAX KW TIME Time-HM X Rate C Time of Maximum kW

RATE C PF AT MAX Fixed-1.3 Rate C Power Factor at Maximum Dmd

RATE D COIN DEMAND Demand Rate D Maximum Coincident Demand

RATE D CUM KM Cumulative Rate D Cumulative kM

RATE D CUM KW Cumulative X Rate D Cumulative kW

RATE D KMH Energy Rate D Total kMh

RATE D KWH Energy X Rate D Total kWh

RATE D MAX KM Demand Rate D Maximum kM

RATE D MAX KM DATE Date Rate D Date of Maximum kM

RATE D MAX KM TIME Time-HM Rate D Time of Maximum kM

RATE D MAX KW Demand X Rate D Maximum kW

RATE D MAX KW DATE Date X Rate D Date of Maximum kW

RATE D MAX KW TIME Time-HM X Rate D Time of Maximum kW

RATE D PF AT MAX Fixed-1.3 Rate D Power Factor at Maximum Dmd

RATE E COIN DEMAND Demand Rate E Maximum Coincident Demand

RATE E CUM KM Cumulative Rate E Cumulative kM

RATE E CUM KW Cumulative X Rate E Cumulative kW

B.16


RATE E KMH Energy Rate E Total kMh

RATE E KWH Energy X Rate E Total kWh

RATE E MAX KM Demand Rate E Maximum kM

RATE E MAX KM DATE Date Rate E Date of Maximum kM

RATE E MAX KM TIME Time-HM Rate E Time of Maximum kM

RATE E MAX KW Demand X Rate E Maximum kW

RATE E MAX KW DATE Date X Rate E Date of Maximum kW

RATE E MAX KW TIME Time-HM X Rate E Time of Maximum kW

RATE E PF AT MAX Fixed-1.3 Rate E Power Factor at Maximum Dmd

READER/PROGRAMMER Alpha-9 X X Reader/Programmer ID

REAL TIME CUM KW Cumulative X Real Time Cumulative kW

REAL TIME MAX KW Demand X Real Time Maximum Demand

REAL TIME TOT KWH Energy X Real Time Total kWh

SCALE FACTOR Fixed-2 X X Scale Factor

SEASON WKDAY HOL SDH X Season, Day of Week, and Type of Day

SEGMENT CHECK All Segment X X Segments

SELF READS Fixed-1 X Number of Self Reads

TEST DEM INT LEN Fixed-2 X X Test Mode Demand Interval Length

TEST MODE K FACTOR Fixed-3.3 X X K Factor in Test Mode

TEST MODE KH Fixed-3.3 X X Kh in Test Mode

TEST TIMEOUT Fixed-3 X X Test Mode Time-out in Minutes

TIME ON BATTERY Time-M X Battery Carryover Time

TIME REMAIN SUBINT Time-MS X X Time Left in Current Subinterval

B.17


TOTAL KM3H Energy X Total kM3h

TOTAL KM3H PULSES Fixed-6 X Total kM3h Pulses

TOTAL KMH Energy X Total kMh

TOTAL KMH PULSES Fixed-5 X Total kMh Pulses

TOTAL KWH Energy X X Total kWh

TOTAL KWH PULSES Fixed-6 X X Total kWh Pulses

TOTAL M3H Energy X Total M3h

TOTAL METRICHOURS Energy X Total Mh

TOTAL WATTHOURS Energy X X Total watt hours

TOU RATE ID Fixed-6 X Rate Schedule ID

TRANSFORMER FACTOR Fixed-6 X X Transformer Factor

USER DISPLAY 1 Alpha-6 X X User Defined Display 1








V ANGLE PHASE A Fixed-3.1 X X Voltage Angle, Phase A

V ANGLE PHASE B Fixed-3.1 X X Voltage Angle, Phase B

V ANGLE PHASE C Fixed-3.1 X X Voltage Angle, Phase C

WH CALIBRATION Fixed-3.3 X X Watthours/Calibration Test Pulse

C.1

Appendix C: Polyphase Service Types

Form 9S/8S, 10A/8A Service Type Table

Meter Form

Service Type

Rotation Va Phase A Vb Phase B Vc Phase C

10/9/8 4WY-120v ABC 120 0 120 120 120 240

4WY-277v ABC 277 0 277 120 277 240

4WY-120v CBA 120 0 120 240 120 120

4WY-277v CBA 277 0 277 240 277 120

4WD-120v ABC 60 0 60 180 104 90

4WD-240v ABC 120 0 120 180 208 90

4WD-480v ABC 240 0 240 180 416 90

4WD-120v CBA 60 0 60 180 104 270

4WD-240v CBA 120 0 120 180 208 270

4WD-480v CBA 240 0 240 180 416 270

Form 29S, 36S (6S), 36A (6A) Service Type Table

Meter Form

Service Type


29, 36 (6) 4WY-120v ABC 120 0 IGNORE 120 240

4WY-277v ABC 277 0 IGNORE 277 240

4WY-120v CBA 120 0 IGNORE 120 120

4WY-277v CBA 277 0 IGNORE 277 120

C.2

Form 45S (5S), 45A (5A) Service Type Table

Meter Form

Service Type


45 (5) 3WY-120v ABC 120 0 IGNORE 120 120

3WY-277v ABC 277 0 IGNORE 277 120

3WY-120v CBA 120 0 IGNORE 120 240

3WY-277v CBA 277 0 IGNORE 277 240

3WD-120v ABC 120 0 IGNORE 120 60

3WD-240v ABC 240 0 IGNORE 240 60

3WD-480v ABC 480 0 IGNORE 480 60

3WD-120v CBA 120 0 IGNORE 120 300

3WD-240v CBA 240 0 IGNORE 240 300

3WD-480v CBA 480 0 IGNORE 480 300

4WD-120v ABC 120 0 IGNORE 104 90

4WD-240v ABC 240 0 IGNORE 208 90

4WD-480v ABC 480 0 IGNORE 416 90

4WD-120v CBA 120 0 IGNORE 104 270

4WD-240v CBA 240 0 IGNORE 208 270

4WD-480v CBA 480 0 IGNORE 416 270

C.3

Form 16/15/14S, 16/15/14A, 16/15/14K Service Type Table

Meter Form Service Type


16/15/14 4WY-120v ABC 120 0 120 120 120 240

4WY-277v ABC 277 0 277 120 277 240

4WY-120v CBA 120 0 120 240 120 120

4WY-277v CBA 277 0 277 240 277 120

4WD-120v ABC 60 0 60 180 104 90

4WD-240v ABC 120 0 120 180 208 90

4WD-480v ABC 240 0 240 180 416 90

4WD-120v CBA 60 0 60 180 104 270

4WD-240v CBA 120 0 120 180 208 270

4WD-480v CBA 240 0 240 180 416 270

3WD-120v ABC 120 0 0 0 120 60

3WD-240v ABC 240 0 0 0 240 60

3WD-480v ABC 480 0 0 0 480 60

3WD-120v CBA 120 0 0 0 120 300

3WD-240v CBA 240 0 0 0 240 300

3WD-480v CBA 480 0 0 0 480 300

3WY-120v ABC 120 0 0 0 120 120

3WY-277v ABC 277 0 0 0 277 120

3WY-120v CBA 120 0 0 0 120 240

3WY-277v CBA 277 0 0 0 277 240

C.4

Form 12S, 12SE, 12K, 25S, 27K (Network) Service Type Table

Meter Form

Service Type


12, 25, 27 3WD-120v ABC 120 0 IGNORE 120 60

3WD-240v ABC 240 0 IGNORE 240 60

3WD-480v ABC 480 0 IGNORE 480 60

3WD-120v CBA 120 0 IGNORE 120 300

3WD-240v CBA 240 0 IGNORE 240 300

3WD-480v CBA 480 0 IGNORE 480 300

3WY-120v ABC 120 0 IGNORE 120 120

3WY-277v ABC 277 0 IGNORE 277 120

3WY-120v CBA 120 0 IGNORE 120 240

3WY-277v CBA 277 0 IGNORE 277 240

D.1

2-Element 3-Wire

FORM 56S

Appendix D: Meter Forms

2/3-Element4-Wire

FORM 9/8S

YK Z

2-Element

3-Wire FORM 12S

Alternate

Positions of

Moveable

Terminal

2-Element 4-Wire

FORM 36S (6S)

K YK

ZK

2-Element 3-Wire

FORM 45S (5S)

2/3-Element 4-Wire

FORM 16/15/14S

2-Element 3-Wire

FORM 25S

2-Element4-Wire

FORM 29S

S-Base Forms

G.2

2-Element 4-Wire

FORM 36A (6A)

K Y Z

2-Element 3-Wire

FORM 45A (5A)

K Y Z

2/3-Element4-Wire

FORM 10/8A

K

Y Z

2-Element3-Wire

FORM 12K

2/3-Element 4-Wire

FORM 16/15/14K

2-Element 3-Wire

FORM 27K

Single Phase 2-Wire

Form 3S

Single Phase 3-Wire

Form 2S

Singlephase Forms K-Base Forms

A-Base Forms

F.1

Appendix E: Definitions 1132Prog/1132Com: 1132Prog/1132Com is Landis+Gyr‘s windows based software package. 1132Prog is the program development portion and 1132Com is the reader/program portion.

ANSI Protocol: ANSI C12.19 is an industry standard communication protocol that is used in the ANSI firmware versions of the S4e meter.

DG1100: DG1100 is the Landis+Gyr‘s DOS based reader/programmer package for DGCOM protocol meters. This software package is no longer current, supports S4 DGCOM meters firmware version 4.41 and earlier and is available only on request.

DGCOM (Data Gyr COMmunications) Protocol: This is the Landis+Gyr Communication Protocol that the S4, Altimus, and S4e DGCOM meters use to communicate to a PC or a handheld device.

Selectable Metric: The selectable metric can be programmed one of the following aspects of energy: kVA/kVAh rms, kVA/kVAh td, kVAR/kVARh td. During a meter read the Selectable metrics registers will appear as KM (for demand) and KMh (for energy).

RS232: RS-232 is a communication, Recommended Standard, for serial interface devices. Using this standard and an RS-232 add-on board the meter can communicate with RS-232 based devices. The RS-232 standard defines communications between two devices only.

RS485: RS-485 is a newer communication standard that is similar to RS-232. Using this standard and an RS-485 add-on board the meter can communicate with RS-485 based devices. The RS-485 standard supports communications between several devices on an RS-485 bus.

Remote Communications Alert: If the External Input field in 1132Prog is set to Communication Alert, 1132Prog will enable the external input polarity field. When programming, the external input will be programmed to send an alert to the modem when open or when closed depending on the value of the external input polarity field. The meter must have a modem and the modem program must include external input as a call in event for the communication alert to result in a call. Communication Alert programming is incompatible with Real Time Rate programming. If Communication Alert is selected in the External Input field, the Real Time field will be set to None or Relays Only. Do not combine Communication Alert programming with Real Time Trigger relays.

Third Metric: The Third metric can be programmed one of the following aspects of energy: kVA/kVAh rms, kVA/kVAh td, kVAR/kVARh td. During a meter read the Third metrics registers will appear as KM3 (for demand) and KM3h (for energy).

VArms: Root mean squared measurement of Volt-Amperes.

VAtd: Time delay (lagging) measurement of Volt-Amperes. At unity power factor VAtd is equal to watts.

VARtd: Time delay (lagging) measurement of Volt-Amperes reactive.

F.1

Appendix F: Block Diagram with Legend

F.2

Legend

Battery – 3.6V Lithium battery for backup during outages maintains timekeeping and registers.

Bus – The connection between the microcontroller and the power measurement IC.

Clock – Maintains the timing for energy and demand calculations

Demand Reset – Switch activates the demand reset sequence.

EEPROM – EEPROM stands for Electronic Erasable Programmable Read Only Memory and is non-volatile storage location for programming constants and for meter data. Data is retained during an outage.

LCD – Display on top of the meter, can be programmed to scroll through 64 displays.

Load Profile Memory –Memory used for storing load profile register data. (32K or 128K for an S4 or 128K only for an S4e)

Microcontroller – Processor that controls the meter, performs data calculations, and meter I/O.

Optical Interface + Calibration Pulse Output – This an ANSI type II optic port that operates as a calibration LED during testing.

Power Line Monitoring – Monitors AC power for line loss detection. After 6 missing line cycles on phase C the meter shuts down, saves data, and runs off the battery in TOU programmed meters.

Power Measurement IC – The power measurement IC analyzes the incoming voltage and current inputs to perform basic measurement calculations.

Power Supply – Converts incoming AC on phase C to low voltage DC for meter operation.

Reed Switch – Switch activated magnetically and used to access Alternate mode and GyrBox mode.

Remote Interface – Serial Port communication used for relay boards, modems, and AMR devices.

Scroll – Scroll is used to deactivate autoscroll and to step through the individual displays.

Surge Protection – The surge protection protects the meter against voltage spikes and surges.

System Oscillator – Crystal controlled oscillator which provides measurement time base.

Test Mode – The test mode switch activates test mode.

Time Clock – Time keeping device maintaining TOU time during power outages.

Voltage Reference – Stable reference used by Power Measurement IC.

G.1

Appendix G: Notes and Notices Current Manuals, Notes, Brochures, etc. can be found on the website www.landisgyr.us. Here are the current links at the time of this manual revision:

Brochures: http://www.landisgyr.us/Landis_Gyr/Meters/Brochures.asp

Manuals: http://www.landisgyr.us/Landis_Gyr/Meters/Manuals.asp

Product Spec Sheets: http://www.landisgyr.us/Landis_Gyr/Meters/Manuals.asp

Product Schedules: http://www.landisgyr.us/Landis_Gyr/Meters/ProdSchedules.asp

Case Studies: http://www.landisgyr.us/Landis_Gyr/Meters/CaseStudies.asp

Tutorials: http://www.landisgyr.us/Landis_Gyr/Meters/Tutorials.asp

Catalog Generation Documents: http://www.landisgyr.us/Landis_Gyr/Meters/CatGen.asp

FAQ‘s: http://www.landisgyr.us/Landis_Gyr//Meters/TechSupportFAQ.asp

Help Desk Info: http://www.landisgyr.us/Landis_Gyr/Meters/ss_cs_meters.asp

Product Application and Update Notices: http://www.landisgyr.us/Landis_Gyr/Meters/TechSupProdUpdate.asp

Product Presentations: http://www.landisgyr.us/Landis_Gyr/Meters/ProductPres.asp

Recent Alerts: http://www.landisgyr.us/Landis_Gyr/Meters/TechSupAlerts.asp

http://www.landisgyr.us/

http://www.landisgyr.us/Landis_Gyr/Meters/Brochures.asp

http://www.landisgyr.us/Landis_Gyr/Meters/Manuals.asp

http://www.landisgyr.us/Landis_Gyr/Meters/Manuals.asp

http://www.landisgyr.us/Landis_Gyr/Meters/ProdSchedules.asp

http://www.landisgyr.us/Landis_Gyr/Meters/CaseStudies.asp

http://www.landisgyr.us/Landis_Gyr/Meters/Tutorials.asp

http://www.landisgyr.us/Landis_Gyr/Meters/CatGen.asp

http://www.landisgyr.us/Landis_Gyr/Meters/TechSupportFAQ.asp

http://www.landisgyr.us/Landis_Gyr/Meters/ss_cs_meters.asp

http://www.landisgyr.us/Landis_Gyr/Meters/TechSupProdUpdate.asp

http://www.landisgyr.us/Landis_Gyr/Meters/ProductPres.asp

http://www.landisgyr.us/Landis_Gyr/Meters/TechSupAlerts.asp